Halliburton - Perforating Solutions

Table of Contents

Perforating Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1-1Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1-1Perforating Solutions History. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1-2Sharing Knowledge to Exceed Customer Expectations . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1-4Manufacturing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1-6Doing the Right Thing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1-7

PerfPro® Process . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-1The Perforation Process . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-2Damaged Zones . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-4Completion Types . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-5Underbalanced Perforating. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-13Extreme Overbalanced Perforating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-15ShockProSM Shockload Evaluation Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-17SurgeProSM Service. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-19Modeling and Evaluation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-21Post-Job Evaluation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-26Bibliography. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-27

Installation Examples . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-1Single-Zone Completions. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-3Horizontal Completions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-6Automatic-Release Gun Hangers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-8Single-Trip Perforating and Testing. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-13Multizone Perforating and Testing. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-14Annulus-Fired Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-17Modular Gun System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-19Enhanced Overbalanced Perforating Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-20Sand Control Solutions. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-22Perforate and Squeeze . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-25Select Fire™ Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-26Live Well Perforating. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-29Downhole Pump Completions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-33Coiled Tubing Perforating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-34

VannGun® Assemblies. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-1History of Perforation Techniques . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-2VannGun® Assemblies 1 9/16 in. to 7 in. and 4 SPF to 21 SPF . . . . . . . . . . . . . . . . . . . . . .4-9VannGun Phasing and Shot Patterns* . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-10VannGun Tables. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-15Scalloped Gun Charge Performance Data . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-27Gun Washover/Fishing Specifications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-29Gun Swell Information. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-30VannGun Pressure Ratings. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-32

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Thermal Decomposition of Explosives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-32Time Vs. Temperature Chart . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-34

Firing Heads . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-1Detonation Interruption Device . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-5Mechanical Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-6Model II-D Mechanical Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-7Model III-D Mechanical Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-8Pressure-Actuated Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-9Model K Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-10Model KV-II Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-11Time-Delay Firer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-12Multiaction-Delay Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-13Annulus Pressure Firer-Control Line . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-14Annulus Pressure Transfer Reservoir. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-15Slimhole Annulus Pressure Firer—Internal Control . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-165-in. Annulus Pressure Transfer Reservoir . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-163 1/8-in. Internal Control . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-163 1/8-in. Annulus Pressure Transfer Reservoir—Internal Control . . . . . . . . . . . . . . . . . . .5-16Differential Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-17Hydraulic Actuator Firing Head and Swivel-Type Hydraulic Actuator Firing Head . . . . .5-18Mechanical Metering Hydraulic-Delay Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-19Slickline-Retrievable Mechanical Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-20Slickline-Retrievable Time-Delay Firer Firing Head. . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-22Extended Delay Fuses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-23Modular Mechanical Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-24HalSonics® Firing Head. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-26Side-Pocket Mandrel Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-28Annulus Pressure Crossover Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-29EZ Cycle™ Multi-Pressure Cycle Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-30Operating the EZ Cycle Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-31

Special Applications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-1DrillGun™ Perforating Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-3Select Fire™ Systems . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-5Isolation Sub-Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-6AutoLatch™ Release Gun Connector . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-7Ratchet Gun Connector . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-8Shearable Safety Sub . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-9Modular Gun System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-10Setting Tools for the Auto-Release Gun Hanger . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-14Detach™ Separating Gun Connector . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-15G-Force® Precision Oriented Perforating System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-16Explosive Transfer Swivel Sub . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-18Eccentric Orienting Tandem . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-19Roller Tandem Assembly. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-20

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Centralizer Tandem . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-21StimGun™ Assembly. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-22StimTube™ Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-24PerfStim™ Process. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-26POWR*PERFSM Perforation/Stimulation Process . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-27Quick Torque™ Connector . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-28Pump-Through Firing Head . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-30

Ancillary Equipment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-1Automatic-Release Gun Hanger—Rotational Set . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-4Automatic-Release Gun Hanger—Automatic-J Mandrel . . . . . . . . . . . . . . . . . . . . . . . . . . .7-6Emergency Release Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-8Y-Block Assembly . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-9Fast Gauge Recorder . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-10Balanced Isolation Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-12Annular Pressure-Control Line Vent . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-14Annular Pressure-Control Line Swivel Sub . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-15Annular Pressure-Control Line Tubing Release . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-16Bar Pressure Vent. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-17Below-Packer Vent Device . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-18Maximum Differential Bar Vent . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-19Pressure-Operated Vent . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-20Vann™ Circulating Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-21Automatic Release . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-22Mechanical Tubing Release . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-24Pressure-Actuated Tubing Release. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-26DPU® Downhole Power Unit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-27SmartETD® Advanced Electronic Triggering Device . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-28Coiled Tubing Conveyed Perforating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-29Fill Disk Assembly. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-30Gun Guides. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-31EZ Pass™ Gun Hanger . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .7-32Hydraulic Metering Release Tool for the Single Trip System (STPP™-GH) . . . . . . . . . . .7-34

Appendix . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-1United States Patents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-1Frequently Asked Questions and Answers. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .8-3

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Introdu

ction

Perforating Solutions

IntroductionHalliburton Energy Services has excelled in delivery of oilfield tools and services for more than 80 years and has continuously set the industry standard. Halliburton Perforating Solutions product line maintains an unequalled success and safety record while continuously developing and introducing new and innovative products. The quality of our products starts with the continuous innovation by our multi-disciplined technology group. Business development groups stay in close contact with technology to assure that clients have the latest technology available. Manufacturing methods, inspection/testing, packaging, and warehousing assure the quality of our products at the point of delivery to operations. Halliburton's commitment to health, safety, environment, and flawless service quality assure that the final product and service is world class.

This catalog will provide the reader with general information about the perforating optimization process as well as provide examples of perforating system installations. In addition, the reader will find useful information about Halliburton perforating products including descriptions, illustrations, and specifications of the following:

• VannGun® assemblies

• Firing heads

• Special applications

• Ancillary equipment

Perforating Solutions offers the most options for perforating configurations and completion optimization including PerfStim™, POWR*PERFSM, PerfConSM, StimGun™, G-Force®

precision oriented perforating system, and modular gun systems.

With the combined strengths of Halliburton’s Jet Research Center's perforating charges and the originators of the VannSystem® completion services, Halliburton Perforating Solutions offers the most experience in the industry. Whatever your perforating needs, Halliburton will always meet and strive to exceed your expectations.

From Tubing Conveyed Perforating to Perforating Solutions

Communication between the formation and the wellbore is of critical importance in cased hole completions. The method in which the guns are deployed in the well is an important detail; however, it is immaterial as long as the most efficient perforating solution is used. Halliburton offers an array of methods, tools, equipment, and products to accomplish this communication. Halliburton Perforating Solutions service line, previously known as Halliburton Tubing Conveyed Perforating (TCP) services is responsible for developing and delivering these solutions.

Since the inception of our VannSystem completion services in 1970, Halliburton has built a reputation for innovative ideas, quality equipment, and dependable operations.

Halliburton Perforating Solutions include the following:

• VannGun assemblies

• Firing heads

• Venting devices

• Release devices

• Debris barriers

• Live well perforating systems

• Gun hangers

• Enhanced overbalanced perforating

• Special applications

• Ancillary equipment

New Perforating Solutions TechnologyHalliburton strives to be the leader in identifying, developing, and commercializing new technology. Some of the more recent technological innovations described in this catalog are listed below:

• PerfPro® process

• HalSonics® firing head

• DrillGun™ perforating system

• Detach™ separating gun connector

• G-Force® internal orienting system

• StimGun™ assembly

• Fast gauge recorder

• New shaped charges

– Millennium™ charges

– Mirage® charges

– Dominator® charges

– Maxim™ charges

• New gun systems

– 5 1/8-in. 21 spf superhole

– 4 3/4-in. systems

– 5-in. systems



– 4 1/4-in. system

– 7-in. 18 spf Mirage system

POWR*PERF, a process of Marathon Oil Company, is licensed by Halliburton. POWR*PERF is a service mark/trademark of Marathon Oil Company and licensed by Halliburton.StimTube™ and StimGun™ are trademarks of Marathon Oil Company and are licensed toHalliburton by Marathon.PerfStim™ is a trademark of Oryx Energy Company.Patented by Oryx and licensed by Halliburton

Introduction 1-1

Perforating Solutions History

There are different methods that can be used to create perforations in wellbores. One of the first was bullet perforating which was conceived and patented in 1926. The major drawbacks with this method were that the bullet remained in the perforation tunnel, penetration was not very good, and some casings could not be perforated effectively.

In January 1945, Ramsey C. Armstrong founded Well Explosives Company, Inc. later to be known as WELEX. In 1946, Welex introduced the shaped charge. The principle of the shaped charge was developed during World War II for armor piercing shells used in bazookas

to destroy tanks. This new technology allowed the oil producers to have some control over the perforating design (penetration and entry hole size) to optimize productivity.

In 1949, McCullough Perforating Company made an attempt at developing tubing conveyed perforating but was not successful.

In 1970, Vann Tool Co., known as VannSystems, developed and ran the first commercially successful tubing conveyed perforating system. Throughout the early years, VannSystems was the leader in

introducing TCP technology in the oil industry. In October 1985, Halliburton purchased VannSystems and since then Halliburton has continued to be the industry leader in research, development, and introduction of new technology to the oil industry.

At the present time, there are specific projects in several locations around the globe that will require Halliburton Perforating Solutions to continue the introduction of new technology and perforating solutions to safely and efficiently handle today's complex completion requirements.

Perforating Solutions Timeline

Year Accomplishment

1970Introduced tubing conveyed perforating via development of the first pressure-balanced mechanical firing head

First successful TCP job—On October 13, 1970, Roy Vann runs the first TCP completion for an independent operator in southeast New Mexico.1971 Introduced stinging VannGun® assemblies through large-bore permanent packers1972 First Vent—Tubing runs in dry, maximizing underbalance

1973First Tubing Release—Actuated via conventional wireline tool, the release drops the VannGun assemblies into the rathole to

eliminate pulling guns out of the hole.Introduced Single Trip Perforating and Testing Systems

1974 Introduced TCP Systems for Gravel Packing—Carefully controlled underbalance pressures with high-shot density, big-hole guns yield improved results for gravel pack operations.

1975 Introduced Dual Completion Systems—VannGun assemblies run in on dual tubing strings to complete isolated zones. Zones can be produced without commingling production.

1980First long interval completion (over 1,000 ft)—Successfully completed a 1,000-ft interval for Shell Oil Company (Offshore California) in a single trip

First bottom shot detection device

1981

First safe Quick-Connect System—The Polymer Alignment Insert (PAI), still an industry standard, greatly enhances safety by recessing and securing detonating cord and boosters inside the gun body or tandem.

First Horizontal Well Completion—The first horizontal well completed using TCP technology was drilled under Canada’s McKenzie River.

Introduced the Time-Delay Firing Head—This firing head also provides for firing several guns independently.

1983 First Azide-Free Bidirectional Boosters—New boosters eliminate hazards created by lead azide sensitivity to shock and heat. Azide-free boosters can safely be installed at the shop and transported to the locations.

1985 First High Temperature TCP System (400°F)1986 First Automatic Release Firing Head—The firing head automatically drops the expended guns into the rathole.1988 First TCP System for Pumping Wells—The benefits of underbalanced perforating brought to well pumping.1989 First Extremely High Temperature (500°F) System1990 Introduced the Slickline-Retrievable Firing Head1991 First TCP Monobore Completion System (i.e., the Auto Release Gun Hanger)1993 First Select Fire™ System—System offers the ability to shoot multiple zones in a single trip at desired time.1994 First Modular Gun System1996 First TCP Snubbing Gun Connector System for Standard BOP Stacks

1997 Introduced AutoLatch™ TCP Gun Connector—The several hours formerly required to make each connection when snubbing into live wells is cut to an average of 20 minutes.

1998First to license StimGun™ Technology—Productivity enhancement is achieved by perforating with propellant. This StimGun

technology is licensed worldwide for both TCP and Wireline Perforating.First DrillGun™—All aluminum drillable gun assembly.

2000 Introduced the Millennium™ VannGun assembly—Offers the best performance in 9 of 11 API tests of the most popular gun systems.2001 Introduced the PerfPro® process for well inflow optimization

1-2 Introduction

Since 1970, Halliburton, originally VannSystems, has performed more than 36,000 perforating jobs. Each VannGun® perforating job has been documented and is stored in a database that is maintained at our Tools, Testing, and Tubing Conveyed Perforating Technical and Engineering Support Facility in Carrollton, Texas.

In addition to documenting relevant well and reservoir information for each job, the database also serves as a measure of technical efficiency. Of all the VannGun jobs performed worldwide, the perforating success is 97.57%. Halliburton employs a classification system that rates each Perforating Solutions job for overall success.

Job Efficiency Table 1993-2004

Presented are additional perforating milestones achieved with the VannGun Perforating System.

2002 Introduced the Mirage® improved low debris perforating system2003 Introduced G-Force® gun system—First internal oriented gun system

2004

Introduced ShockProSM software program to evaluate mechanical risk factors to well components from gun detonation shock loads Introduced SurgeProSM software program to model a variety of dynamic wellbore calculations

Introduced HalSonics® firing head designed to actuate guns by sending an acoustic signal down the tubingIntroduced Dominator® shaped charge to optimize perforating performance in reservoir rock

Introduced Maxim™ shaped charges for applications where multiple strings of casing are to be perforated Introduced Quick Torque™ connector to simplify TCP gun assembly and save time by eliminating assembly of components on the rig

Developed composite DrillGun™ perforating system that combines rugged, reliable perforating components with the versatility of drillable materials Introduced EZ Cycle™ multi-pressure cycle firing head that can be cycled several times prior to firing the perforating guns

Introduced EZ Pass™ gun hanger to run in conjunction with the modular gun system and designed with slips that stay retracted during the perforating event until the tool is set

Perforating Solutions Timeline

Year Accomplishment

Perforating Classification SystemClass Results

1 Successful job, no problems2 Non-Halliburton problem (could not run in hole, packer set off-depth, etc.)3 Perforating misrun and/or more than 1-hour downtime4 Halliburton tool problem (non-Perforating problem)

Perforating MilestonesMilestone Results

Longest overall perforating job (gross) 9,370 ftLongest perforated interval (net) 7,600 ft

Most firing heads in one run 62Deepest completion measured depth 30,521 ft

Highest temperature 460°F

100.00

99.50

99.00

98.50

98.00

97.50

97.00

96.50

96.00

95.50

95.001993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003

Job

Effic

iency

Years

2004

Introduction 1-3

Sharing Knowledge to Exceed Customer Expectations

While state-of-the-art equipment and procedures continue to be developed to enhance operational efficiencies in the oilfield, one significant enhancement to the way in which oilfield procedures are handled today does not relate to equipment. It concerns the method in which operators, engineers, and suppliers are now conducting their business relationships. Internal and external web portals are now used to improve expedience in alignment and communication between all supplier and operating personnel. Halliburton’s extranet portal, www.myHalliburton.com or “Intelligence Central™” portal provides personalized, user-friendly, web-based access to technical content, tools, and applications that allow cross-functional teams to collaborate in a single, easy to access environment. myHalliburton.com® portal’s organizational architecture is structured around the oil and gas development through production workflow addressing Asset Discovery, Evaluation of the Asset, Completions, Well Maintenance, and Formation/Production Enhancement. The Perforating Solutions Completion Products and Services section of the workflow contains perforating well completion product specifications and catalog content, current best practices, case histories, simulators, and technical tools that provide users with improved technology and best practice integration for

reduced operating expense and improved reserve development.

myHalliburton.com creates efficiencies by providing transparency to the technical and commercial workflow tools and applications in a single, user-friendly environment that can be personalized to meet the goals of all users by:

• Decreasing initial tendering time frames through collaborative web applications

• Accessing commercial information such as invoices, field tickets, job schedules, and proposals, allowing users to view the entire commercial workflow for a particular service job; reducing the disputes that can increase operating expenses for oil companies and suppliers

• Accessing portal communities which can remove the problems inherent in coordination of remotely located personnel

To gain access to the Halliburton electronic business portal, log on to www.myHalliburton.com. Please note, the myHalliburton.com portal requires a user name and password to gain access. Consult your local Halliburton representative for registration information.

myHalliburton.com Home Page

1-4 Introduction

Halliburton is committed to providing world class solutions. The Perforating Solutions Knowledge Management Portal is an exciting new tool that provides a virtual location for Halliburton perforating experts to expand and share knowledge and best practices. Topics such as firing systems, perforating systems, and special completion applications are discussed and highlighted around the globe via the web-based portal. The system gives Halliburton’s perforating community the extra edge in providing the right information at the right time to improve safety, service quality, and the quality of the solution.

Features

• Provides Halliburton’s experts with easy access to written information (tool manuals, drawings, etc.)

• One-on-one interaction, monitored by a subject matter expert (SME) to capture new knowledge

• Coordinates processes and prioritizes issues that require SME input

• Provides the latest technology in real time

Knowledge Portal Screen Capture

Introduction 1-5

Manufacturing

Product quality is the primary objective at Halliburton’s Jet Research Center (JRC). There is a registered ISO Quality system, which is an ideal business approach for managing costs and providing products to customers to meet their needs. The quality system consists of documented processes that are assessed annually for proper implementation. The success of the quality process is dependent, not only on management, but on all employees. Employees are empowered to make decisions for removing questionable or defective products from the system when discovered. All are encouraged to make suggestions for improvements, including safety and protection of the environment. The quality process is owned by all JRC employees—not just the Quality department.

One of the keys to our quality success is our motto, “Take care of the customer.” To achieve this goal requires pursuit of continual improvement. Not all improvements are monumental in size or scope. Improvements are usually made in small increments that turn into a successful project or solution. In addition to our external customers, we have internal customers to take care of as well.

Our commitment to quality products starts with the design by technology and continues through the entire process with proper documentation of orders by customer service, quality of purchased parts, manufacturing methods, inspection/testing, packaging, warehousing, and final delivery to the customer. Everyone plays an important part.

Management support is required for the system to be implemented in a manner to deliver results. This means the management team must be committed to making the tough decisions required when building quality into the products.

The quality team works with technology, purchasing, and manufacturing to pursue continual improvement. Processes, methods, and procedures are reviewed for windows of

opportunity to create improvements. Corrective and preventive action is taken where necessary to affect change. Inspection plans are being implemented on selected purchased materials to assure quality parts are available and delivered to the manufacturing team in a timely manner.

The process of continual improvement results in change, training, and review to determine the effectiveness. Some recent accomplishments or problems solved are as follows:

• Realized more consistent targets and greater penetration of targets now than in the past

• Improved powdered metal blending to reduce spoilage and deterioration

• Achieved main load powder improvements

• Improved data recording and documentation (notes, traceability, marking/identification, test fire charts, etc.)

• Reduced incidence of delivery of damaged material for charge holder tubing

• Reinstated sampling inspection to identify problem products

• Improved use of SAP to download quality and supplier performance data

• Improved packaging of charges to reduce deterioration

• Covered more calibration of equipment without redundancy

• Increased surveillance of vendor performance

• Eliminated poor-performing vendors

Success can be attributed to continuously improving the quality of our processes and products measured by the elimination of poor quality and the satisfaction everyone shares with doing the job right the first time.

1-6 Introduction

Doing the Right Thing

Planning with the Halliburton Performance Improvement Initiative (PII)

Planning for Superior Health, Safety, Environmental, and Service Quality performance using Halliburton’s Performance Improvement Initiative (PII)

PII is Halliburton’s annual planning process for improving HSE and Service Quality. Since its introduction in 1997, PII has helped to ensure organizational alignment in the quest for continuous improvement and has yielded demonstrable results. PII includes a review of past performance, an assessment of currently available tools, and the development of objectives and strategies for continuous global improvement.

Focusing on PreventionPII is primarily focused on the prevention of incidents. PII introduced tools such as the Halliburton Management System (HMS) that facilitates the integration of HSE and Quality into the way we do our work. Site surveys, hazard observation, and risk analysis help control dangerous conditions.

Executive PII Teams

Region/Country PII Teams

Safety &

Health

S&H SQ E

Area PII Teams

S&H SQ E

Service

QualityEnvironment

Each year since 1997, Halliburton executive teams have set strategies and objectives then review, approve, and monitor region/country plans.

Monthly global conference calls led by executive teams assess progress and provide a platform for best practice exchanges and discussions

of barriers to success.A

UD

ITP

RO

CE

SS

HMS PROCESS DOCUMENTATION

SITE SURVEY

PRE/LEFTof ZERO POSTINCIDENT FOCUS

“0”

CPI

RISKASSESSMENT

PREVENTION IMPROVEMENT CORRECTION

JSA

NEAR MISS

INCIDENT

INVESTIGATION W/

FEEDBACK

ROOTCAUSE W/

FEEDBACK

HAZARD OBSERVATION

Introduction 1-7

Objectives

Service Quality• Perform at the highest levels and exceed customer

expectations

Safety and Health• Establish visible evidence of leadership in all employees

• Eliminate fatalities

• Eliminate lost time and recordable injuries

• Eliminate vehicle accidents

Environment• Identify the top five high risk behaviors

• Achieve closure on outstanding assessment/audit issues

• Track incidents and prevent their recurrence

• Determine significance of our environmental inventory

• Manage our chemicals

RecognitionAt the end of each year, the executive teams evaluate the progress to plan and award Regions/Countries with the PII President’s Award for exemplary accomplishment.

ResultsSince the implementation of PII, thousands of employees have been trained in HSE leadership, risk evaluation and management, causal analysis and corrective action, environmental awareness, process documentation, and integrated HSE management. Annual employee surveys show increasingly favorable views of the company’s HSE values, and injury rates have been reduced by over 50%.

Halliburton Historical Recordable Incident Rates

Halliburton Historical Lost Time Incident Rates

0

0.5

1

1.5

2

2.5

1995 1996 1997 1998 1999 2000 2001 2002 2003 2004

0

0.5

1

1.5

2

2.5

3

3.5

4

4.5

1995 1996 1997 1998 1999 2000 2001 2002 2003 2004

1-8 Introduction

Introduction 1-9

Operational Safety

As with all Halliburton jobs and services, safety comes first. Halliburton Perforating Solutions provides the inherent safety of perforating with the well under full control. Surface flow equipment is in place, the packers set, and BOP stack closed.

Firing system designs do not include electrical detonators, eliminating problems caused by stray electrical currents. Azide-free boosters and an innovative connector system that protects detonating cord and boosters enhances surface safety. Halliburton firing systems require hydrostatic pressure or the application of tubing or annulus pressure to fire. In situations where a mechanical firing head is the only choice, Halliburton requires its Detonation Interruption Device to prevent accidental firing.

Safety and reliability are the building blocks of Halliburton's Perforating Solutions's industry leading reputation. The company designs its systems with safety as the foremost consideration, using only top quality materials in the construction of its equipment and following wellsite procedures that help ensure safe operations and reliable results. Halliburton uses non-electrical detonators, bidirectional boosters, non-lead azide explosives, specialized gun connection inserts, low shrink detonating cord, and advanced firing head technology. Halliburton uses one of the highest grades of steel in the industry to create guns and has complete traceability of materials in all its equipment. The company's long and extensive experience in completing oil and gas wells has helped create an unparalleled record of safe, reliable operations.

Explosive Safety and Security

Halliburton maintains an explosive safety program which strives to deliver the following:

• Promote a culture that recognizes and identifies the hazards associated with the handling, storage, and transportation of explosives

• Provide guidelines and procedures for safe handling, storage, transportation, and use of explosives

• Maintain global uniformity in procedures followed by Halliburton employees when using explosives

• Provide training to all employees on safety and security while using, handling, storing, and transporting explosives

• Maintain compliance with applicable governmental regulations and HES policies

• Recognize best practices as established by industry standards, guidelines, and recommended procedures

• Maintain limited access to secure storage of explosives

The industry organizations establishing standards include, but are not limited to:

• Institute of Makers of Explosives (IME)

• American Petroleum Institute (API)

• National Fire Protection Association (NFPA)

• Bureau of Alcohol, Tobacco, and Firearms (BATF)

• U.S. Department of Transportation (DOT)

• International Marine Dangerous Goods (IMDG)

• International Air Transport Association (IATA)

• Mine Safety and Health Administration (MSHA)

Implementation of Halliburton's Performance Improvement Initiative tools and processes combined with perforating-specific HSE efforts has led to industry-leading performance in the areas of Health, Safety, Environment, and Service Quality.

1-10 Introduction

PerfPro

® P

rocess

The Halliburton PerfPro® Process

Introduction

The Halliburton PerfPro® process takes a systematic approach to delivering engineered perforating systems. The process is based on extensive experimental work at Halliburton's Perforation Flow Laboratory and includes perforation flow modeling and damage assessment performed with a fully three-dimensional finite-element model. To deliver the highest possible completion efficiency, the PerfPro process also utilizes experimental testing, modeling, and field validation studies to optimize perforation selection and execution.

The final step in a natural cased and perforated completion requires a way to establish communication between the

reservoir and the wellbore to efficiently produce or inject fluids. The most common method involves perforating with shaped charge explosives to get through the casing and cement sheath. Numerous perforating strategies are available. These include choices of gun type, charge type, shots per foot (spf), shot phasing, gun position, and degree of under- or overbalanced pressure at the time of perforating. Since perforating is typically the sole means of establishing communication with the reservoir, it is critically important that this aspect of the completion receive the proper engineering focus.

Perforated Wellbore Geometry

Damaged ZoneDiameter

(Caused By Drilling)

CasingDiameter

Cement Sheath

PerforationSpacing

(Dependent OnShot Density)

Entrance HoleDiameter In

Casing

Phase Angle

PerforationLength

(Cement To EndOf Perforation)

Perforation Diameter

Crushed Zone Diameter

Casing

HAL

1532

4

PerfPro® Process 2-1

The Perforation Process

The shaped charge or jet perforator is the explosive component that creates the perforation and uses the same technology as armor-piercing weapons developed during World War II. These shaped charges are simple devices, containing as few as three components. However, optimizing charge performance is not an easy matter due to the physics of liner collapse and target penetration. The extreme dynamic conditions that exist during collapse and penetration involve calculation concerning elasticity, plasticity, hydrodynamics, fracture mechanics, and material characterization.

The process of liner collapse and jet formation begins with detonating the base of the charge. A detonation wave sweeps through the explosive, chemically releasing energy. High-pressure gases at the detonation front measure approximately 3 to 5 million psi and impart momentum, forcing the liner to collapse on itself along an axis of symmetry. Different collapse and penetration characteristics will result depending on the shape and material of the liner. If the liner geometry is conical, a long, thin stretching jet will be formed. In this case, the penetration of the jet into the target is relatively deep, and the hole geometry is small.

If the liner is parabolic or hemispherical, a much more massive, slower-moving jet will be formed, creating a shallow penetration with a relatively large hole diameter. Because liner design has a tremendous influence on the penetration characteristics of a shaped charge, the shape of the liner is used to categorize jet perforators as either deep-penetrating (DP) or big hole (BH). Typical DP charges create hole diameters between 0.2 and 0.5 in. with penetration depths in concrete of up to several dozen inches. DP charges are primarily used for perforating hard formations. BH charges are generally used for perforating unconsolidated formations that require some form of sand control. BH charges are designed with hole diameters of between 0.6 and 1.5 in. to facilitate placement of sand or proppants, and penetrations are normally 8 in. or less.

Shaped Charge Perforator

Explosive

Liner

CaseH

AL15

325

2-2 PerfPro® Process

Formation

Casing

Fluid Gap

Carrier

ConicalLiner

Slug

1 2

3 4

5

Later Stages of LinerCollapse ProduceSlower-Moving Slug

Stretching JetPenetrates Formation

JetPenetratesCarrier

LinerCollapsesto FormJet

1 2

43

5

Formation

Casing

Fluid Gap

Carrier

ParabolicLiner

RelativelySlow-Moving Jet

Concentric ofMaterial

Large Hole inCasing

Small Hole inCarrier

LinerCollapseandInversion

JetExpansion

SlowlyStretchingJet

Slug

Deep-Penetrating Sequence

Big Hole Sequence

HAL

1213

2H

AL12

131


Damaged Zones

During the jet penetration process, some damage occurs to the rock matrix surrounding the perforation tunnel. The altered area, called the damaged (crushed and compacted) zone, results from high-impact pressures that occur during perforating. A damaged zone consists of crushed and compacted grains forming a layer approximately 0.25 to 0.5 in. around the perforation tunnel (Asadi and Preston, 1994; Pucknell and Behrmann, 1991). Later work by Halleck et al. (1992) shows that damaged zones are of nonuniform thickness and decrease down the length of the perforation tunnel. Some evidence suggests BH charges may cause damaged zone layers that approach 1 in. around the perforation tunnel. In addition, laboratory studies indicate

that the permeability of the damaged zone can be 10 to 20% of the surrounding formation (Bell et al., 1972). Accordingly, it is very important to design the perforation event to minimize this effect on well performance.

Perforation-Damaged Zone

Sand Grains Prior to Perforating Event

Sand Grains After Perforating Event

HAL

1200

1

HAL

1200

0Damaged

Permeability, fromDrilling, Production

or Injection kd

UndamagedPermeability, k

Cement

Casing

Open Perforation

Charge and Core Debris

Pulverization Zone

Grain Fracturing Zone

Compacted Zone(With Damaged Permeabilityfrom Perforating, )kc

HAL

1532

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Completion Types

The effectiveness of the communication path through the cement and casing is critical to the completion and well performance. Perforations should enhance well productivity in several ways. They should create clear channels through the portion of the formation damaged during the drilling process. They should provide uniform tunnels for hydraulic fracturing fluids and proppants and should make many large uniform holes for sand control and hydrocarbon production.

Completions can be classified into four types: openhole, natural, stimulated, and sand control. However, in every case, the objective is to maximize production which, in turn, can be modeled using the radial flow equation:

The productivity index (PI), typically used to assess the performance of a well over time, is derived from the following radial flow equation:

Skin Factor

The skin factor or S term is usually defined as a zone of reduced (or higher) formation permeability near the wellbore. Drilling and completing a well normally results in reduced formation permeability around the wellbore. These decreases in permeability can be caused by the invasion of drilling fluid into the formation, the dispersion of clay, and the presence of mudcake or cement. A similar effect can be produced by reductions in the area of flow exposed to the wellbore. Partial well penetration, limited perforating, or plugging of perforations would also result in a damaged formation response.

The skin factor can be used as a relative index to determine the efficiency of drilling and completion practices. The factor is positive for a damaged well, negative for a stimulated well, and zero for an unchanged well.

The total skin factor summarizes the change in radial flow geometry near the wellbore due to flow convergence, wellbore damage, perforations, partial penetration, and well deviation.

Pressure Distribution in a Reservoir with a Skin

Pe Pwf–qμβ

7.08 × 10-3kh---------------------------- ln

rerw----- ⎝ ⎠

⎛ ⎞ S+=

PIq

Pe Pwf–----------------------

7.08 × 10-3kh

μβ ln rerw------

⎝ ⎠⎜ ⎟⎛ ⎞

S+

-------------------------------------------= =

St Sc θ+ Sp Sd ΣSi+ + +=

Wellbore

Pressure In Formation

Pressure Drop Across Skin

Flowing Pressure

Skin

Static Pressure

Skin Or ZoneOf AlteredPermeability

p

HAL

1532

7


The term Sc+θ represents the effects caused by partial penetration and slant as described by Cinco-Ley et al. (1975). Skin effects caused by partial penetration and slant are often significant and result from operational considerations, such as drillsite location and avoidance of coning undesirable gas or water.

Where htD is formation thickness dimensionless, θd is well deviation (sum of the deviation and the true dip—the angle that the wellbore makes with an imaginary normal to the zone), degrees, and θ ′d is adjusted well deviation, degrees.

Where

The term y is equal to the distance between the top of the sand and the top of the open interval, ft.

The term rwc is equal to the corrected wellbore radius, ft.

Sθθ′d41--------⎝ ⎠

⎛ ⎞–2.06 θ′d

56--------⎝ ⎠

⎛ ⎞1.865

log10htD100---------⎝ ⎠

⎛ ⎞–=

Where htDhtrw------

⎝ ⎠⎜ ⎟⎛ ⎞ KH

KV--------=

θ′d tan-1 KHKV-------- tanθd

⎝ ⎠⎜ ⎟⎛ ⎞

=

Sc 1.35=hthp------ 1–

⎝ ⎠⎜ ⎟⎛ ⎞ 0.825

ln htKHKV-------- 7+

⎝ ⎠⎜ ⎟⎛ ⎞

0.49 0.1 ln+ htKHKV--------

⎝ ⎠⎜ ⎟⎛ ⎞

– ln rwc( ) 1.95–⎩ ⎭⎨ ⎬⎧ ⎫

rwc rw( )exp 0.2126Zmht

-------- 2.753+⎝ ⎠⎜ ⎟⎛ ⎞

for y 0>=

Zm y hp 2⁄( )+=

rwc rw y 0=,=

When Zmht

-------- 0.5 replace Zmht

-------- by 1Zmht

--------–⎝ ⎠⎜ ⎟⎛ ⎞

,>


The term Sd represents the effects of formation damage attributed primarily to filtrate invasion during the drilling process. This filtrate invasion can reduce the productivity of an openhole completion and severely impair the performance of the perforated completion, especially when the perforation tunnels terminate inside the damaged zone. Karakas and Tariq (1988) quantified Sd for both openhole and perforated well completions. They also developed a technique to calculate skin effect resulting from perforations based on phasing and perforation length. A calculation for perforation skin effect (Sd)p can be approximated by taking into account formation damage:

This relationship is appropriate for perforations that terminate inside the damage zone (Lp < rd). The term rs

represents the damaged zone radius and (Sd)o is the

equivalent openhole skin effect.

For perforations that extend past the damaged zone (Lp > rd), the amount of damaged skin can be

approximated by:

Here Sp' is the perforated skin evaluated at Lp', the modified

perforation length, and rw' is the modified radius. These

parameters are given by:

And

In both cases, skin caused by the perforation, Sp, is expressed

by three distinct components: horizontal plane-flow effects, Sh, wellbore effects, Swb, and the vertical converging effect, Sv.

The term ΣSi includes pseudoskin factors such as phase and

rate-dependent effects. This term is less important to the total skin factor. Accordingly, the focus should be on understanding and controlling the other skin factors that influence well productivity.

A complete understanding of skin and its effect on completion efficiency is vital to optimizing well productivity.

The Halliburton PerfPro® perforation analysis program was developed to assist in this effort by analyzing these effects for various gun systems.

Inclined, Partially Completed, and Off-Centered Well Configuration

Sd( )p

KKs------ 1–⎝ ⎠

⎛ ⎞ lnrsrw------

⎝ ⎠⎜ ⎟⎛ ⎞

S+=

Sd( )o

KKs------ 1–⎝ ⎠

⎛ ⎞ Sp+=

Sd( )o

KKs------ 1–⎝ ⎠

⎛ ⎞ lnrsrw------

⎝ ⎠⎜ ⎟⎛ ⎞

=

Sd( )p

Sp Sp′–=

Lp′ Lp 1KsK------–⎝ ⎠

⎛ ⎞ rd–=

rw′ rw 1KsK------–⎝ ⎠

⎛ ⎞ rd–=

Sp Sh Swb Sv+ +=

h = completion

thicknessw

zw = elevation

zw zw

rw

rw

hw

hwh h

Vertical Well Slanted Well

O

HAL

1532

8


Natural Completions

“Natural” completions can be defined as those wells with sufficient reservoir permeability and formation competence to produce economical hydrocarbon rates without stimulation. With natural completions, effective communication to the undamaged formation becomes critical. The primary perforation factors are depth of penetration, charge phasing, the effective shot density, percentage of the productive interval that is perforated, and degree of underbalance pressure. The perforation diameter is generally unimportant if it is larger than 0.25 in.

Recent experiments at Halliburton's Perforation Flow Laboratory highlight the importance of optimizing the degree of underbalanced pressure. Perforation damage can occur from perforating with overbalance, balance, and underbalance. All three experiments were perforated under the same test conditions with the same shaped charge, pore pressure, and effective stress condition. The only variable in the three experiments were the degree of underbalanced or overbalanced pressure at ± 3,500 psi.

Overbalanced or balanced perforating has a significant disadvantage. Well fluids injected into the core can potentially damage the formation through fluid invasion and plugged perforations. Because there is no perforation cleanup, the results are larger positive skin values. In the underbalanced experiment, the entire perforation tunnel was effectively cleaned during the instantaneous surge and subsequent flowback period. Whereas, with the balanced and overbalanced experiments, the entire perforation tunnel was not cleaned as efficiently, resulting in much lower core flow efficiencies.

Note that all three cores were flowed and injected at the same flow rates to simulate well cleanup during field conditions. Underbalanced perforating creates negative differential across the formation during the perforation, offering significant benefits. Maximum perforation cleanup can be applied to the entire perforation interval from the surge effect with no fluid invasion into the reservoir.

Alignment of Perforation with Preferred Stress Plane

Overbalanced

Balanced

Underbalanced

Deep Penetrating

HAL

1099

7H

AL10

999

HAL

1100

1


Stimulated Completion

Stimulated completions are typically either hydraulically fractured or acidized or a combination of the two. Hydraulic fracturing is performed to increase the effective wellbore radius, rw, and is usually performed in reservoirs with extremely low permeabilities (k < 1 md). In hydraulic fracturing, fluids and proppants are injected at high pressure and rate (to alter the stress distribution in a formation) and create a fracture or crack in the rock. The perforation strategy can be critical to the success of a planned stimulation treatment. In long intervals or multi-zone treatments, the proppant or acid may cover only part of the interval or enter only one zone because of permeability variations.

Limiting the number and diameter of perforations can increase the pressure in the casing to a point where intervals of lower stress may be fractured. This pre-fracture technique is called “limited entry” perforating. The perforation diameter and uniformity are important because they are the limiting factor in creating pressure restrictions in the well and providing a sealing surface for ball sealers if needed.

Completion success for stimulated wells is influenced by three perforation effects: perforation erosion, perforation bridging, and perforation phasing. The success of the limited-entry technique depends on the differential pressure across the perforation. Perforation erosion leads to loss of differential pressure, improper placement of proppant or acids, and a poor stimulation treatment. Obtaining the most uniform perforation helps minimize this friction component and fluid shearing.

Perforation bridging reduces the effective shot density of the completion and potentially causes early screenout of the stimulation treatment. At proppant concentrations greater than 6 lbm/gal, the perforation diameter should be six times greater than that of the proppant diameter as suggested by Gruesbeck and Collins (1978).

Perforation phasing has been studied in great detail, and its importance to the successful placement of proppant is recognized. Fractures preferably initiate and propagate in a plane perpendicular to the minimum stress direction. If the perforations are not aligned with the preferred stress plane, fluids and proppants will travel through an annular path around the casing to initiate or propagate the fracture plane. This tortuous path may cause higher treating pressure, premature screenout, and asymmetric penetration of the fracture wings. The work by Hazim Abass et al., shows the effects of not having the perforations aligned properly with the preferred stress plane. Studies by Warpinski (1983) and Daneshy (1973) indicate that if the perforations are not within 30° of preferred stress plane, the fracture may initiate on a plane different than the perforation.

To ensure success during stimulation when the preferred stress plane is unknown, a 60° phased gun should be utilized to minimize the perforation and stress plane offset. To fully maximize stimulation performance, it is also important to accurately define the near-wellbore stress field and orient the perforations at 180°. Proper gun orientation maximizes perforation to fracture flow communication and minimizes breakdown pressures to initiate fracturing.

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Oriented PerforationUnoriented Perforation


Acidizing is a stimulation process used to repair formation damage caused by the drilling or perforation process. Injecting acids below fracturing rates allows the acid to dissolve any plugging in the perforations or pore throats, removing damage from the matrix rock. Perforation hole size is less important since proppants are not normally utilized. If a “ball-out” acid job is planned, specially designed shaped charges or bullet perforators are desirable because they create a uniform hole size with no burr on the casing. Bullet perforators will improve the ability of the ball sealers to seal on the casing wall. However, bullet perforators still create a less than desirable slug or carrot that typically remains in the perforation tunnel impairing well productivity.

Acid fracturing is usually performed on carbonate formations to etch the surface of the hydraulically induced fracture. The etched surface significantly improves the effective wellbore radius, making the job less operationally complex because proppants are not required. The disadvantages of acid fracturing are the expense of the fluids and the non-uniform leakoff which results in “wormholes” with potentially untreated formation intervals.

0 0.08 0.15 0.21 0.27 0.31 0.58

0 2 4 6 8 10 30

10

8

6

4

2

0

Tap Water

100-cp HEC solution

Bridging region

Maximum particle concentration (vol/vol)

Maximum gravel content (lbm/gal)

Pe

rfo

ratio

nd

iam

ete

rA

ve

rag

epa

rtic

led

iam

ete

r

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Wellbore

Channel tofracture wings

Perforation

Restrictionarea

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Fracture Orientation to Perforation Not Within 10° to 30° of the Fracture Plane.


Sand Control Completions

Sandstone formations that are not structurally competent often produce sand along with formation fluids. Fluid movement through the reservoir produces stress on the sand grains because of fluid pressure differential, fluid restrictions, and overburden pressure. If these stresses exceed formation cohesive strength, sand is produced and near-wellbore permeability is altered. Sand production can lead to some undesirable results. These include the plugging of perforations, casing, tubing or surface facilities; casing collapse due to changing overburden stress; the destruction of downhole and surface equipment; and costly sand disposal.

In a natural completion, formation fluids entering the perforation tunnels can flow unimpeded into the wellbore. In the gravel packed completion, a series of filters is created to hold back the formation sand while producing formation fluids. Fluid flow entering the perforation tunnel of a gravel packed well must flow linearly through the sand and gravel in the perforation tunnel and inside the annulus of the well before entering the gravel pack screen. The linear flow path is only a few inches; however, the materials inside the flow path have a tremendous impact on well productivity. Inflow performance for a cased gravel-packed completion can be expressed as follows:

For a specific well, this simplifies to:

Wellbore Cross-Section for a Natural Completion and a Cased Hole Gravel-Packed Completion

Pwfs Pwf–qβμ1

1.1271 × 10-3kg A---------------------------------------------- 9.107 × 10-3

β qβ( )2

ρl

A2-------------------------------------------------------+=

Pwfs Pwf–C1q

Kg A-------------

C2q2

A2-------------+=

Typical Cased HoleCompletion

Cement

Casing

ProductionTubing

Packer

PerforationsOilReservoir

Cement

Casing

ProductionTubing

Packer

Perforations

Screen Gravel

Screen

2 in Formation SandPermeability

500 md

Fluid Flow3 bbl/D perforation

0.8 cp Oil

Pressure Drop14.79 psi4.84 psi

Tunnel Diameter0.4 in.0.7 in.

40-Mesh GravelPermeability27,500 md

Typical Cased HoleGravel-Packed Completion

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The two key parameters to well productivity (q) for a gravel packed completion are the area open to flow (A) and the permeability of the gravel in the perforation tunnel (kg). The area open to flow (A) is essentially the number of perforations multiplied by their respective cross-sectional flow area. Gravel pack sand permeability is typically many orders of magnitude higher than the formation permeability with values up to 40,000 darcies common.

The key perforating strategy for gravel-packed completions is to make sure that high permeability gravel pack sand can be placed in the perforation tunnel, which means removing perforating debris and crushed formation material. Perforation damage when perforating overbalanced and underbalanced with big hole charges includes crushed sand grains and liner debris that remain in place with the balanced and overbalanced test shots. Perforation impact on the sand grains surrounding the perforation tunnel includes crushed sand grains or fines that are generated. Insufficient underbalanced pressure leads to perforation damage that can adversely affect injectivity and sand placement.

The greater the perforation density and hole diameter, the smaller the pressure drop through each perforation and the slower the fluid velocity. This promotes the creation of a stable arch around the perforation and reduces the influx of formation fines that can lead to screen erosion or plugging of the gravel pack. Perforation phasing is important to maintain uniform flow patterns around the wellbore, resulting in lower fluid velocities and formation sand movement. High shot density guns (> 12 spf) with spiral phasings provide optimum flow area and flow patterns while maintaining casing integrity.

In some semi-consolidated formations, it may be possible to complete the well and manage sand production without traditional screens in place. High shot density perforating with deep penetrating charges may be utilized to maintain the stable arch and manage sand production. Deep penetrating charges provide greater depth of penetration into undamaged formation material while destroying a smaller radius around the perforation tunnel. Charge phasing is critical to maximize the vertical distance between perforations and maintain formation integrity between perforations.

Restricting the flow of fluids is another way to avoid collapse of the stable arch. Another approach to managing sand production is to orient perforations in the direction of maximum principal stress. Perforations oriented to maximum principle stress result in more stable perforation tunnels that are less susceptible to collapse or sand production. Selective perforating to avoid weaker sand members along with oriented perforating is an effective strategy to avoid gravel packing and the potential for reduced well productivity.

In field operations in unconsolidated sandstones, stable arch bridges occur at the set producing rate. When the producing rate is adjusted, sand production may occur for a short period of time until a different shaped stable arch occurs.

Overbalanced Perforating with Big Hole Charge

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Underbalanced Perforating with Big Hole Charge

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Underbalanced Perforating

Underbalanced perforating occurs when the pressure in the wellbore is lower than the pressure in the formation. The level of pressure differential is important to create open, undamaged perforations and optimize well productivity. Overbalanced perforating without flow typically results in a perforation tunnel with severe tunnel plugging due to crushed formation material and charge debris. Overbalanced perforating with cleanup flow reveals that typically most of the charge debris is removed. However, a low permeability zone due to perforation jets remains. The ideal underbalanced example shows that all perforation damage has been removed with the proper differential applied across the perforation.

King et al. (1985) and others have published the results of a large number of underbalanced perforating jobs in which initial well productivity was compared to subsequent well productivity after acidizing.

Recent laboratory studies performed by Halliburton suggest higher underbalanced pressures are required to achieve clean undamaged perforation tunnels. The work by Folse et al. (2001) shows that in addition to focusing on underbalanced pressure as it is defined in our industry, some consideration needs to be given to the so-called “dynamic” underbalanced pressure.

Dynamic underbalanced pressure refers to the transient fluid gradients on the millisecond time regime that occur due to fluid movement or fill-up of the free gun volume or other artificial surge chambers in the downhole assembly. A perforation job pressure record from a high-speed recorder samples pressures at 100,000 samples per second. Note that even though this well was perforated with approximately 3,300 psi overbalanced pressure, the minimum surge pressure was 695 psi during the initial transient period following detonation.

Underbalanced Perforating

s Acid did not improve production

s

Acid did not improve productionAcid did improve production

LEGEND

l

l

ll l l

ll

l

l

s

sss

s s ss

s

s

sssls sssss

sss ss

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0.1

0.01100 1000 10000

TOTAL UNDERBALANCE PSI

FO

RM

AT

ION

PE

RM

EA

BIL

ITY

MD

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100

1000

1

0.1

0.01100 1000 10000

TOTAL UNDERBALANCE PSI

FO

RM

AT

ION

PE

RM

EA

BIL

ITY

MD

Acid did not improve productionAcid did improve productionProblems

LEGEND

n

n

l

sss

s

sl

ll

ll l l

ll

l

ll

s ssss sssss

ll ll l

l

s

ss

ss

s

Casing Collapse

Stuck Packer

nls

sl

Oil

Gas

Overbalanced Perforation Before Flowing

Cement

Casing

ChargeDebris

Crushed andcompacted low-permeabilityzone

Overbalanced Perforation After Flowing Part of low-permeabilityzone stillexists

Perforationpartiallyplugged withcharge debris

Ideal Underbalanced Perforation Immediately After Perforation

Low-permeabilityzone and chargedebris expelledby surge offormation fluid

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Experiments in Halliburton's Perforation Flow Laboratory have verified that dynamic surge pressure is an actual event that can be controlled in field applications. In some actual experiments, the only variable that changed was free gun volume with a subsequent effect on perforation tunnel cleaning capability. Note that both cores were shot at balanced perforating conditions with an effective stress of 3,000 psi. The core shot with the higher dynamic underbalanced volume did not exhibit any perforation plugging, resulting in a much higher core flow efficiency.

The goal is to achieve the highest underbalance pressure that will yield optimum productivity without

compromising well integrity. The instantaneous underbalance must be followed with continued sustained flow of several gallons per perforation to further clean the perforation and remove the crushed rock and other materials that have been loosened. This critical point is well documented in literature; however, on many jobs it is overlooked due to operational constraints. These constraints include how hydrocarbons are handled at the surface, increased completion cycle time, complexity due to well control operations, and the increased risk of sticking perforation or wireline-conveyed guns due to debris movement.

High-Speed Pressure Recorder Data

14000

0

12000

10000

8000

6000

4000

2000

6,450 psi

695 psi

Guns fire

7.50 7.70 7.90 8.10 8.30 8.50

Time (sec)

3,150 psi

Pore Pressure

11,800 psi

Pre

ssure

(psi)

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Berea test shot balanced with effective stress at 3,000 psi and dynamic volume at 308 cc.

Berea test shot balanced with effective stress at 3,000 psi and dynamic volume at 1,430 cc.

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Extreme Overbalanced Perforating

In many formations, the remaining reservoir pressure or underbalance is insufficient to effectively clean the perforations as suggested by King et al. (1985) and others. In other cases, where formation competence is questionable and the risk of sticking perforating assemblies is greater, sufficient underbalance pressure is not possible. To address the perforation damage in these cases, some (Handren et al. 1993, Pettijohn and Couet, 1994; Snider and Oriold, 1996) have suggested using extreme overbalanced (EOB) perforating, which is a near-wellbore stimulation technique. EOB perforating also provides perforation breakdown in preparation for other stimulation methods, and therefore, eliminates the need for conventional perforation breakdown methods.

The EOB technique involves pressuring the wellbore with compressible gases above relatively small volumes of liquid. The gases have a high level of stored

energy. Upon expansion at the instant of gun detonation, the gases are used to fracture the formation and divert fluids to all intervals. The high flow rate through relatively narrow fractures in the formation is believed to enhance near-well conductivity by extending the fractures past any drilling formation damage. Recently, Marathon Oil Company incorporated proppant carriers into the perforation assembly to introduce proppants into the flow path as the gun detonates. The POWR*PERF SM process, patented by Marathon Oil Company, further enhances productivity by scouring the perforations to leave some residual conductivity on the fracture plane.

Most EOB perforating jobs are designed with a minimum pressure level of 1.4 psi/ft of true vertical depth. For optimum results, it is suggested to utilize the highest possible pressure level without compromising wellbore integrity or operation safety.

Typical Extreme Overbalanced (EOB) Perforating Assembly

Packer

Bauxite

VannGun®Assembly

WellheadIsolation Tool

Nitrogen

300 ft of Fluid

RadioactiveCollar

Tubing

Pressure-OperatedVenture Firing Head

ProppantCarrier

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Along with standard EOB perforating with applied pressure from compressible gases and proppant carriers, propellant-assisted perforating techniques are becoming more widely accepted. The StimGun™ assembly, patented by Marathon Oil Company, combines solid propellant technology with conventional perforating. The StimGun assembly may be utilized for either EOB or conventional underbalanced perforating. The hardware utilized for either system remains the same aside from added protection by using centralizer rings to protect the brittle propellant material.

The propellant sleeve in the StimGun assembly simply slides over the perforation scalloped carrier and is held in position on the gun with the centralizer rings. The propellant material is potassium perchlorate, an oxidizer that burns rapidly, creating carbon dioxide gas. As the shaped

charges detonate, the propellant is ignited by extreme heat from the gun system. As it burns, the propellant generates carbon dioxide gas at high peak pressures typically well above the formation fracture gradient. The StimGun assembly is an effective method for mild stimulation (fractures on order of 2 to 9 ft) for treating near-wellbore problems.

One of the benefits of licensing the StimGun assembly technology is the access gained to the proprietary design called the PulsFrac™* program. PulsFrac software package is utilized to safely design EOB perforating or propellant-assisted perforating jobs. The PulsFrac software output indicates anticipated peak pressure and the degree of fracturing that can be expected. PulsFrac software is a very useful tool for screening candidate wells for types of EOB perforating techniques and for identifying potential operational issues.

*PulsFrac is a trademark of John F. Schatz Research and Consulting, Inc.

Centralizer

RA Marker

Safety Joint

RetrievablePacker

Fill Disk

Firing Head

Fast GaugeRecorder

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StimGun™ Assembly

PulsFrac™ Analysis Report Extreme Overbalanced (EOB/StimGun™ Job)


ShockProSM Shockload Evaluation Service

Engineer Perforated Completions to Evaluate the Mechanical Integrity of All System ComponentsRelying on old rules of thumb or utilizing standard mechanical configurations to cover all perforating cases can lead to catastrophic results. To help avoid such potential disasters, Halliburton utilizes its proprietary ShockPro™ software package* to evaluate the mechanical risk factors of all well components to ensure that all aspects of HSE and Service Quality are covered.

Advanced System for Analyzing Every Completion or Reservoir’s Unique CharacteristicsHalliburton’s ShockPro service determines the dynamic pressure behavior during the perforation event in addition to the solid loading that is imparted to the tubulars, packers, and other completion hardware in the perforating assembly.

Accuracy - Physics Based Numerical ModelingPhysics based numerical model accounts for fluid dynamics and dynamic failure of solids by accounting for the following forces:

• Pressure on surfaces

• Drag

• Internal stress waves and reflections

• Gravity

The time-marching finite differences technique is applied as the numerical method for both fluids and solids. The software is compiled on a personal computer and typically executes in times of several minutes to several hours, depending on complexity of job design. The following failure modes are accounted for in the numerical solution:

• Tubing burst / collapse

• Packer axial load / differential

• Tubing axial buckling or bending

• Tubing compressive / tensile yield

• Gun burst / collapse

• Gun compressive / tensile yield

• Casing burst

• Sump packer / bridge plug axial load

• Wireline tensile yield / pull-out

Buckling / Collapse of Tubing Joint Below Retrievable Packer During Perforating Event

*Software programs used under license from John F. Schatz Research and Consulting, Inc.

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ShockPro™ Software Graphic Display with Error Flags for Tubing Yield and Buckling FailureThis information is utilized to determine the peak pressure applied to a packer, for instance the maximum tension or compression on a joint of pipe or the differential pressure applied to the packer. Once dynamic failure criteria have been established, ShockPro software can be utilized to examine whether or not potential problems may occur with a given perforating assembly.

Steps can then be taken to correct unusually high peak loads to manage job risk factors. The physics based model has been validated special high speed recorders that sense pressure, temperature, and acceleration at sampling frequency on the order of 115,000 samples per second.

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SurgeProSM Service

Halliburton’s SurgePro™ perforating-design software program* is robust and can be used for a large variety of dynamic wellbore calculations. The sub-models contained in the program are physics-driven and rely on measurable or estimated actual input parameters, no curve fitting or back of the envelop calculation.

As a result, the SurgePro program is ideal for predicting:

• Wellbore, perforation, and gun pressurizations

• Wave propagation—fluid injection/production

• Perforation behavior—perforation damage

• Completion integrity—burst/collapse and packer differential

Accuracy—Physics Based Solution with Documented ValidationThe SurgePro program is based on a proprietary analysis developed from:

• API Section IV perforation flow laboratory studies

• Time marching finite difference modeling

• High-speed pressure measurements

• Empirical field data

Mass, momentum, and energy are conserved for each time step. The solution is derived by using energy release equations for the gun, simultaneous coupled finite-difference solutions of the Navier-Stokes equations for wellbore, perforation and fracture flow, and solid rock mechanics for perforation breakdown.

Capability to Model a Wide Range of Wellbore ConditionsTo fully represent dynamic wellbore behavior, the SurgePro program takes into account a wide variety of factors:

• Thermodynamic mixing and multiple compressible fluid types/phases

• Various energy sources, including perforating gun ignition, and residual energy deposition (gun, well, and perforation tunnel)

• Valves, pumping, and orifices

• Multiple diameter effects in the well including:

- Surface pressurization, pumping, and flow back of fluids

- Flow into and breakdown of perforation tunnels- Subsequent transient return flow from perforations

A typical screen capture from SurgePro™ software simulation; understanding and prediction of dynamic pressure behavior becomes paramount when conventional underbalance techniques are not an option.

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Dynamic underbalance is created with the application of a special fast opening surge vent assembly. Note the gauge reading atmospheric pressure in the chamber prior to the perforating event following a sustained minimum surge pressure across the perforated interval of ± 1,000 psi for 0.5 seconds.

This minimum surge pressure across the formation results in a dynamic underbalance 3,200 psi that can potentially improve well productivity. The high speed gauge readings are in good agreement with the theoretical prediction from the physics based model. Hundreds of high-speed pressure records have been collected under varying well conditions to validate the modeling results generated.

Identical sandstone targets perforated with the same 39 gram shaped charge at the same reservoir pressure and effective stress condition. The picture on left is perforated in a balanced condition and the picture on the right is perforated ideally with 3,000 psi underbalance pressure. The difference in productivity or core flow efficiency in this case is on the order of 82% by not completely cleaning up the perforation tunnel with proper underbalance pressure or differential surge flow. In cases where conventional underbalance perforating is not applicable, it may be possible to apply the SurgePro service to create a localized dynamic underbalance pressure to overcome the perforation damage or skin factor associated with balanced or overbalanced perforating techniques while still maintaining well control.

*Software programs used under license from John F. Schatz Research and Consulting, Inc.

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Actual High Speed Field Pressure Measurement

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Balanced Underbalanced

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Modeling and Evaluation

Halliburton's PerfPro® process is a systematic approach to optimize well inflow performance by proper selection of the gun system, charge type, shot density, phasing, conveyance method, and well condition (overbalanced or underbalanced pressure). PerfPro software is a web-based application that analyzes the effects of downhole conditions on perforator

performance and productivity. The PerfPro program performs calculations for charge performance (formation penetration and perforation hole diameter) and well productivity (productivity index and total skin). The PerfPro workflow is designed to provide optimum perforating conditions and prediction of gun system performance.

PerfPro® Workflow

Start:Open PerfPro

®

Before you startEnsure that all web browsers areclosed before starting PerfPro.

Change limits ofmeasurement

Start a new job? No Open a job file

Yes

Create a new job file

Configure generalinformation

Configure completioninformation

Configure well information

Configure PerforationPenetration Model

information

A

A

No

Yes

Calculateproductivity index?

Configure reservoirinformation

Display results

Configure a report

Save a job file

Upload a job fileto the web

Save a file to the post jobdata collection

Export a job fileto Well Evaluation Model

End:Exit PerfPro

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Halliburton's PerfPro® charge performance calculations for penetration are based on proprietary models derived from theoretical and experimental studies carried out at Jet Research Center (JRC), a Halliburton Company. API RP-19B defines the procedure for evaluating gun system performance at surface conditions in unstressed concrete targets. A fully loaded gun system is perforated in actual casing surrounded by concrete, and the target penetration, casing entrance hole, and burr height are recorded. Halliburton's PerfPro program transforms API RP-19B Section I surface test data to downhole conditions by correcting for the formation compressive strength and effective stress. The associated downhole charge performance takes into account the gun positioning, casing grade, wellbore fluid density, and well condition.

PerfPro® Charge Performance Calculations

Casing

Gun

Water

Steel Form

28-DayConcrete

TestSpecimen

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API Section 1 Concrete Target

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The primary objective of the Halliburton PerfPro® process is to optimize gun selection and job execution to deliver the highest productivity index or lowest skin factor. Therefore, after charge performance values are calculated, the PerfPro program makes a productivity index and skin factor assessment. The PerfPro process accounts for skin factors due to perforation, drilling damage, partial penetration, non-Darcy flow, and well deviation. A fully three-dimensional

(3D) flow model is utilized, as described by Ansah et al. 2001, to characterize the skin component due to perforation geometry. Input well parameters and calculated charge performance values are linked to an artificial neural network, trained by the 3D finite element model, to generate the perforation skin component. The productivity index and total skin factor are corrected, utilizing analytical calculations for well inclination, partial penetration effect, non-Darcy flow, and drilling damage effects.

CHARGE PERFORMANCE REPORT

General Data

Reservoir fluid type Oil Mid-Perforation Depth 3250.0 ft - TVDBorehole Diameter 12.25 in Reservoir Pressure 1464.0 psiPorosity 24.0 % Reservoir Temperature 112.0 °FPermeability 1191.0 md Completion Fluid Type DieselFormation CompressiveStrength

3891.0 psi Completion Fluid Density 6.83 lb/gal

Drilling Damage Radius 3.0 in Lithology Sandstone

Completion Data

Casing Description 1Outer Diameter 9.63 inInner Diameter 8.68 inGrade N-80Weight 47.0 lb/ft

Perforator Information

Gun 1 Gun 2 Gun 3Charge Name 7"

MILLENNIUM

4"MILLENNIUM

4-1/2"MILLENNIUM

Charge Type DP SDP SDPCharge Loading, gm 39.0 39.0 22.7Phasing, deg 45.0 60.0 30.0Shot Density, spg 12 5 12Gun Position Eccentered Eccentered EccenteredAvg Formation Penetration, in 40.68 43.22 23.78Avg Entrance Hole Dia*, in 0.36 0.29 0.28API 5th Edition Section IDataTotal Target Penetration, in 43.3 52.0 26.8Entrance Hole Diameter, in 0.36 0.37 0.38

PRODUCTIVITY REPORT

Completion DataReservoir Fluid Type Oil Well Deviation @ Perfs 56.2 degDrainage Radius 1500.0 ft Net Sand Thickness 27.0 ftPseudo-Skin due to WellDeviation

-0.697 Perforated Total Length 27.0 ft

Distance To Top Perf Interval 0.0 ftSkin due to Partial Penetration 0.0

Reservoir DataPermeability 1191.0 md Reservoir Pressure 1464.0 psiAnisotropic Ratio, kV/kH 0.2 Reservoir Temperature 112.0 °FFormation Volume Factor 1.1 bbl/stb Porosity 24.0 %Formation Fluid Viscosity 4.36 cp API Gravity 32.6 °API

Perforator InformationGun 1 Gun 2 Gun 3

Charge Name 7"MILLENNIUM

4"MILLENNIUM

4-1/2"MILLENNIUM

Gun Position Eccentered Eccentered EccenteredShot Phasing, deg 45.0 60.0 30.0Shot Density, spf 12 5 12Avg Formation Penetration, in 40.68 43.22 23.78Avg Entrance Hole Dia, in 0.36 0.29 0.28Underbalance Condition, psi -350.0 -350.0 -500.0

Productivity AnalysisTotal Skin Perforation Skin Productivity Index, STB/day/psi

Gun No. 1 -0.666 0.031 7.2Gun No. 2 -0.158 0.539 6.682Gun No. 3 0.319 1.016 6.261


PerfPro® Graph Example

PerfPro® Graph Example

To

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ressu

reD

rop

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1600

1400

1200

1000

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600

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200

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Total Pressure Drop Vs Flow Rate

Gun No.1 Gun No.2 Gun No.3

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Total Skin

PI

Gun 2

Gun Number

Gun 1 Gun 36.2

7.2

To

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kin

Pl and Total Skin Vs Gun

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The Halliburton Perforation Flow Laboratory (API RP-19B Section IV)

The petroleum industry often evaluates gun systems solely on the results of an API RP-19B Section I test, choosing the gun system with the longest penetration in concrete or largest hole diameter. Unfortunately, the shaped charge manufacturers are well aware of this selection process and design and optimize their shaped charges for peak performance in unstressed concrete. Basing the perforation selection on Section I test data can lead to inefficiency in the shaped charge design process and in transforming surface data to downhole conditions.

API RP-19B has provisions for a testing setup to evaluate shaped charges at conditions as close as possible to downhole conditions with Section IV testing. In the Perforation Flow Laboratory, a formation core can be perforated with a single shaped charge at reservoir pressure, effective stress, and a given well condition (underbalanced or overbalanced). This special testing apparatus allows each shaped charge to be evaluated by perforating in actual formation material as opposed to unstressed concrete. The core can be injected or flowed into after perforating to characterize the degree of perforation damage and cleanup as a function of the perforating condition. Following the perforating flow study, the core can be removed and the actual perforation geometry (tunnel length, shape, and damage) measured.

Utilizing the Halliburton Perforation Flow Laboratory puts the focus on completion efficiency as a function of the way the perforation job will be executed at field conditions. This allows a more accurate way to assess perforator efficiency than simply evaluating Section I penetration results. For instance, a given charge may penetrate 2 in. deeper in a Section I target; however, if the charge cannot be shot with sufficient underbalance to effectively clean the perforation tunnel, then the full potential of the given shaped charge may never be realized. Core samples evaluated in the Perforation Flow Laboratory under the same conditions of pore pressure, effective stress, and charge type illustrate the importance of an underbalanced condition. The only variable changed between the two samples is the well condition. One sample was shot balanced and shows perforation damage due to plugging. The other sample shows that the entire perforation tunnel is completely open to flow when sufficient underbalanced pressure is applied.

Simplified Perforation Flow Facility Schematic

Core Sample

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Flow PathAfter Perforation

WellboreChamber

Shaped Charge

OverburdenPressure Vessel

WellborePressure

OverburdenPressure

Underbalanced

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Overbalanced


Post-Job Evaluation

The petroleum industry as a whole has begun to focus on designing/executing perforating jobs to achieve optimum completion efficiency. However, the validation of this process is generally somewhat lacking. The Halliburton PerfPro® process completely optimizes post-job information to quantify well productivity, then gathers and archives that information into the PerfPro database. This

allows Halliburton's deployed technical advisors to access a global perforation database that directly links the method by which we perform perforating services to completion efficiency. This powerful tool allows Halliburton to offer technically sound engineered perforating solutions with empirical data to support the solution.

Post-Job Database Example

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Bibliography

1. Asadi, M. and Preston, F.W.: “Characterization of the Jet Perforation Crushed Zone by SEM and Image Analysis,” SPEFE (June 1994) 135-139.

2. Pucknell, J.K., and Behrmann, L.A.: “An Investigation of the Damaged Zone Created Perforating,” paper SPE 22811, 1991.

3. Halleck, P.M., Atwood, D.C., and Black, A.D.: “X-Ray CT Observations of Flow Distribution in a Shaped-Charge Perforation,” paper SPE 24771, 1992.

4. Bell, W.T., Brieger, E.F., and Harrigan Jr., J.W.: “Laboratory Flow Characteristics of Gun Perforations,” JPT (Sept. 1972) 1095-1103.

5. Cinco-Ley, H., Ramey Jr., H.J., and Millar, F.G.: “Pseudoskin Factors for Partially Penetrating Directionally Drilled Wells,” paper SPE 5589, 1975.

6. Karakas, M., and Tariq, S.M.: “Semianalytical Productivity Models for Perforated Completions,” paper SPE 18247, 1988.

7. Gruesbeck, C. and Collins, R.E.: “Particle Transport Through Perforations,” paper SPE 8006, 1978.

8. Abass, H.H. et al: “Oriented Perforation - A Rock Mechanics View,” paper SPE 28555, 1994.

9. Warpinski, N.R.: “Investigation of the Accuracy and Reliability of In-Situ Stress Measurements Using Hydraulic Fracturing in Perforated Cased Holes,” Proceedings - Symposium on Rock Mechanics (1983) 24, 773-786.

10. Daneshy, A.A.: “Experimental Investigations of Hydraulic Fracturing Through Perforations,” Journal of Petroleum Technology (October 1973) 25, 1201-1206.

11. King, G.E., Anderson, A. and Bingham, M.: “A Field Study of Underbalance Pressures Necessary to Obtain Clean Perforations Using Tubing-Conveyed Perforating,” paper 14321, 1985.

12. Folse, K., Allin, M., Chow, C. and Hardesty, J.: “Perforating System Selection for Optimum Well Inflow Performance,” SPE paper 73762, 2002.

13. Handren, P.J., Jupp, T.B., and Dees, J.M.: “Overbalance Perforation and Stimulation Method for Wells,” paper SPE 26515, 1993.

14. Pettijohn, L., and Couet, B.: “Modeling of Fracture Propagation During Overbalanced Perforating,” paper SPE 28560, 1994.

15. Snider, P.M., and Oriold, F.D.: “Extreme Overbalance Stimulations using TCP Proppant Carriers,” World Oil (Nov. 1996) 41-48.

16. Ansah, J., Proett, M., and Soliman, M.Y.: “Advances in Well Completion Design: A New 3D Finite-Element Wellbore Inflow Model for Optimizing Performance of Perforated Completions,” paper SPE 73760, 2002.


Installation

Exam

ples

Installation Examples

Single-Zone Completions (page 3)

Single-zone completions help minimize perforating costs while maximizing potential. This section describes typical single-zone completions as well as perforating below a permanent packer and how each component of the completion functions to provide quality, cost-efficient solutions.

Horizontal Completions (page 6)

Horizontal completions allow for perforating of long horizontal intervals, which maximizes the productive potential of these completions at the same cost as single-trip perforating. In addition, by combining orienting fins, swivels, and low-side VannGun® assemblies, shots can be oriented toward fracture planes or other needed areas of completions.

Automatic-Release Gun Hangers (page 8)

Automatic-release gun hangers (ARGH) allow perforating and testing of a zone without downhole restrictions. The perforating assembly can be positioned and retained adjacent to the desired interval. The drillpipe or tubing is then removed. Once surface equipment is installed, guns are automatically detonated and released in the bottom of the well.

Single-Trip Perforating and Testing (page 13)

Single-trip strings combine the benefits of tubing conveyed perforating and advanced testing technology to save rig time. Sophisticated, accurate Halliburton data collection technology provides the information necessary to evaluate formation potential.

Multizone Perforating and Testing (page 14)

Multizone completions include dual completions and selective completions. Halliburton dual completions help maintain maximum underbalance and reduce costs while enhancing flexibility. When combining a Y-block with Halliburton sliding sleeves, multiple zones can be perforated, tested, and selectively produced through a single string.

With piggy back multizone completions, it is possible to perforate and test the lower zone, and then perforate the upper zone, commingling flow from both zones for the second test—all in a single trip.

Annulus-Fired Systems (page 17)

Annulus-fired systems are ideal for situations when nitrogen is unavailable or too costly. Tubing runs in dry or with a minimal fluid pad. Annulus-fired systems let you fire the guns without pressuring the tubing—maintaining maximum underbalance.

Modular Gun System (page 19)

The modular gun system brings tubing conveyed perforating advantages to monobore completions without creating flow restrictions. It also eliminates the need and cost for tubing between guns and the packer.

Enhanced Overbalanced Perforating Solutions (page 20)

These completions include POWR*PERF™, PerfStim™, StimTube™, and StimGun™ systems. Each increases productivity by incorporating different perforating techniques.

Sand Control Solutions (page 22)

Sand control techniques include Shoot and Pull, STTP™-GH Single-Trip Perf/Pack, screenless FracPacSM, and PerfConSM

processes. All provide innovative, cost-efficient solutions.

Perforate and Squeeze (page 25)

The perforate and squeeze method utilizes single-trip block squeeze (DrillGun™ system), which cuts rig time and kill-fluid costs by using a single-trip procedure.

Select Fire™ Systems (page 26)

Select Fire™ systems utilize dual and multiple zone perforating and testing. These methods offer unprecedented flexibility including the ability to test two zones in one trip; isolating two zones for selective testing and perforating; and selective testing and perforating of an unlimited number of zones.

POWR*PERF, a process of Marathon Oil Company, is licensed by Halliburton. POWR*PERF is a service mark/trademark of Marathon Oil Company and licensed by Halliburton.StimTube™ and StimGun™ are trademarks of Marathon Oil Company and are licensed to Halliburton by Marathon.PerfStim™ is a trademark of Oryx Energy Company.Patented by Oryx and licensed by Halliburton.

Special Applications 1Installation Examples 3-1

Live Well Perforating (page 29)

Live well perforating utilizes ratchet connectors or AutoLatch™/release gun connectors. The ratchet connector is conducive to snubbing into live wells much faster without a drilling rig. The AutoLatch connector combines coiled tubing economies with perforating benefits.

The isolation sub-assembly is a more economical tool which may be utilized on wells with lower surface pressures.

Downhole Pump Completions (page 33)

Rod pump completions offer the advantages of underbalanced perforating in rod-pumped wells and are able to keep fluids away from sensitive formations.

Coiled Tubing Perforating (page 34)

Coiled tubing is another method used in the industry to deploy perforating guns into a well. The firing mechanisms used to detonate the guns are hydraulically operated. The firing heads are the ball drop actuator firing head, which is also available with a swivel; and pressure-actuated firing heads such as TDF, model K, KV-II, etc.

2 Special ApplicationsSpecial Applications 23-2 Installation Examples

Single-Zone Completions

Closed System

Single-zone completions help minimize perforating costs while maximizing potential. This string runs in virtually dry to create maximum underbalance without swabbing or nitrogen blow-down costs. Redundant firing heads minimize delays caused by firing problems.

Open System

Replacing a vent with the ported balanced isolation tool (BIT) provides for underbalanced perforating and replaces the fill disk and perforated sub.

The BIT’s design separates the clean fluid below it from the kill fluids above it. It runs in with the ports open, allowing circulation at any point. Once the guns are positioned, circulation removes debris from the tool’s glass disk. Before firing, swabbing or displacing fluids with nitrogen provides for an underbalance.

Radioactive Sub

RetrievablePacker

Model II-D orModel III-DPressure-AssistedFiring Head

Automatic Release

ProfileNipple

Radioactive Sub

RetrievablePacker

MechanicalFiring Head

DetonationInterruption Device

Maximum DifferentialBar Vent

Tubing Release

VannGun Assembly®

Time-DelayFiring Head

VannGun Assembly

BalancedIsolation Tool

Single-ZoneClosed System

Single-ZoneOpen System

HAL

8145

HAL

1540

1


With Circulation Valve

To limit underbalance pressures, the Vann™ circulating valve runs in open but closes automatically when a predetermined pressure is reached.

With Pressure-Operated Tools

Halliburton developed this string of pressure-operated tools when the use of wireline is not feasible.

Pressure-Operated Vent

Pressure-OperatedTubing Release

Circulating Valve

Model II-D or Model III-DPressure-AssistedFiring Head

VannGun Assembly®

Time DelayFiring Head

Hydraulic Packer

Radioactive Sub

Tubing Joint

RetrievablePacker

Vann™Circulating Valve

Bar PressureVent


VannGun Assembly®

Time-Delay Firing Head

Profile Nipple

Vann™ Circulating Valve Pressure-Operated Tools

HAL

1540

2

HAL

5869


Perforating Below a Permanent Packer

Guns Sting Through Packer

Perforating charge explosives deteriorate rapidly at high downhole temperatures. (See the Time vs. Temperature chart in Section 4.) Running and setting a large-bore packer on wireline, then stinging the perforating string through it minimizes the charges’ exposure to high temperatures. Once the perforating string is spaced out, circulating mud and heavy fluids out of the tubing string establishes underbalance.

This design offers another advantage. If required, the guns can be retrieved without drilling out the packer.

Guns Run With Packer

Running VannGun® assemblies with the permanent packer eliminates the packer bore restrictions on gun size. This allows larger guns to be run. The packer and guns are run in on drillpipe, tubing, or wireline.

String design places the VannGun assemblies across the interval to be perforated when the packer is set. After displacing mud and heavy fluids out of the tubing to create the underbalance, the tubing seal is stung into the packer and the guns fired.

Permanent Packerwith Sealbore Extension

Balanced IsolationTool

Mechanical TubingRelease (optional)


VannGun Assembly®



VannGun Assembly®


Permanent Packer


MechanicalTubing Release(Optional)


Profile Nipple

HA

L8

14

7

HA

L11

79

9

Guns Sting Through Packer Guns Run With Packer


Horizontal Completions

This string perforates extremely long horizontal intervals, maximizing the productive potential of horizontal completions while providing the economies of single-trip perforating.

Typically, the string incorporates short, but widely separated gun sections. Using pressure-actuated Halliburton time-delay firing heads on each gun eliminates misfires caused by the breaks that so frequently occur in long firing trains. Since the guns fire virtually simultaneously, all intervals are perforated and underbalanced.

Explosive Transfer Swivel Sub

The explosive transfer swivel sub was designed to allow two sections of guns to rotate independently of one another. This independent rotation is important on long strings of guns in horizontal wells when it is necessary to orient them in a specific direction. It is easier to orient several short sections of guns than one long gun section.

This swivel sub can be run as a connector between two guns to allow them to rotate independently without breaking the explosive train. In other words, this sub passes on the explosive transfer to the next gun.

Swivel Sub Installation

Retrievable Packer(Optional)

Orienting Subs VannGunAssembly

®

Tubing Swivel

Ported Nippleand Time-Delay Firer

Ported Nippleand Time-Delay Firer

Explosive TransferSwivel Subs

HA

L1

05

07

HA

L1

59

94

Retrievable Packer

PortedNipple


VannGunAssembly

®

Tubing Spacers

Horizontal Completion


G-Force® Precision Oriented Perforating System

The combination of orienting fins, swivels, and low-side VannGun® assemblies keep shots oriented toward fracture planes or other areas of interest in horizontal completions.

The recent introduction of the G-Force® internal orienting system allows very accurate gravity based charge

orientation. This system features an internal orienting charge tube assembly and gun carrier, which allows perforating in any direction, irrespective of the gun's position relative to the casing.

G-Force® System

Retrievable Packer

Fill DiskG-Force

®

System

HA

L1

53

96

Annulus PressureCrossover

Pressure-OperatedVent




Automatic-Release Gun Hangers

For high volume testing and production, the automatic-release gun hanger (ARGH) allows perforating and testing of a zone without imposing downhole restrictions. The perforating assembly can be positioned and retained adjacent to the desired interval. The drillpipe or tubing is then removed. After all surface equipment is installed, the guns are detonated and then released automatically into the bottom of the well.

ARGH Completion Below a Retrievable Packer

When using an ARGH completion below a retrievable packer, the completion uses the maximum desired underbalance. Modular design allows for the use of less make-up space. Additional perforations may be added through the tubing at a later date. Other benefits include no tubing required between guns and packer, no wireline work required to drop the assembly, and no restrictions left in casing below the packer.

ARGH Completion Below a Retrievable Packer

VannGunAssembly

®

ARGHSet

ARGHRelease

RetrievablePacker

On-OffTool

HA

L1

54

13


ARGH Completion Below a Permanent Packer

When using an ARGH completion below a permanent packer, the permanent packer sets on wireline, while the ARGH and guns are run on the workstring. Other benefits include less risk of presetting the packer, and lower pressure needed to fire guns since setting the packer requires no pressure. One of the main benefits of using the ARGH completion below a permanent packer is that the production tubing is run and tested independently of other tools.

ARGH Completion Below a Permanent Packer

ARGHRelease

PermanentPacker

On-OffTool

VannGunAssembly

®

ARGHSet

HA

L1

54

14


Monobore Completion Below a Permanent Packer

When using a monobore completion below a permanent packer, production tubing and a permanent packer are installed before running the ARGH assembly. This allows retrieval and replacement of the perforating assembly without tripping expensive production tubing. Remedial work can be performed without pulling production equipment. Other benefits include having the guns on bottom for a shorter period of time, and the use of lower firing pressures since production equipment is tested prior to installing guns in the well.

ARGHSet

ARGHRelease

PermanentPacker

On-OffTool

VannGunAssembly

®

HA

L1

54

15

Monobore Completion Below a Permanent Packer


Monobore Completion Below a Polished Bore Receptacle

When using a monobore completion below a polished bore receptacle (PBR), production tubing and seal assembly are installed in the PBR and tested before running the ARGH and guns. The full ID of the liner and production tubing can be used for fluid flow, while the sealbore of the PBR is protected from any damage that might occur. Other benefits include having the guns on bottom a shorter period of time.

ARGHSet

ARGHRelease

Polished BoreReceptacle

On-OffTool

VannGunAssembly

®

HA

L1

54

16

Monobore Completion Below a Polished Bore Receptacle


ARGH Completion Below an Electric Submersible Pump

The ARGH completion below an electric submersible pump (ESP), allows the well to be perforated underbalanced, while continuing production via the ESP. No tubing is required below the pump, and since the guns are not connected with the tubing, they do not transmit any mechanical shock. Even in wells with casing too small to run a tubing string along the ESP, all benefits of TCP are provided.

ARGHSet

ARGHRelease

Electric SubmersiblePump

On-OffTool

VannGunAssembly

®

HA

L1

54

17

ARGH Completion Below an Electric Submersible Pump


Single-Trip Perforating and Testing

These one-trip strings combine the benefits of Halliburton tubing conveyed perforating and advanced Halliburton testing technology that save rig time. Perforating underbalanced removes damage that can adversely impact data accuracy and production. Sophisticated, accurate Halliburton data collection technology provides the information needed to evaluate the formation’s potential.

Halliburton one-step procedures incorporate redundant well control systems—surface control equipment in place, Halliburton downhole safety valves, and tester valves. This

schematic illustrates tools typically used in single-zone, one-step perforate and test procedures. Well conditions, economics, and testing objectives determine the specific tools used.

All tools are pressure-operated, eliminating the rig-time costs involved in calling out and running wireline equipment. The annulus pressure firing head provides the benefits of tubing conveyed perforating in situations when heavy muds or regulations preclude the use of drop bars.

OMNI™ Valve

BIG JOHN®Jars

Safety Joint

Annulus PressureTransfer Reservoir

Packer

Circulating Valve

Pressure-OperatedVent

Annulus Pressure FiringHead with ExtendedMechanical Firing Head

VannGun Assembly®

Collet Assembly

Slip Joints

Radioactive Sub

OMNI™ Circulating Valve

Sampler

Gauge Carrier andHMR Gauges

Safety Joint

CHAMP®IV Retrievable

Packer

Balanced Isolation Tool

Tubing Release

Firing Head

VannGun Assembly®


Select Tester Valve®

Bypass

Gauge Carrier andHMR Gauges

Vertical and RadialShock Absorbers

Perforated Tailpipe

Pressure TransferControl Line

HA

L1

59

78

HA

L1

59

79

Single-Trip Perforating and Testing


Multizone Perforating and Testing

Piggy Back Multizone Completion

With this system, it is possible to perforate and test the lower zone, and then perforate the upper zone, commingling flow from both zones for the second test—all in a single trip. The upper zone can be evaluated by comparing data from the two tests.

Retrievable Packer


Mechanical TubingRelease


VannGun Assembly®


VannGun Assembly

HA

L1

53

94

Piggy Back Multizone Completion


Dual-String Completion

This typical dual-zone Halliburton VannSystem® configuration maintains maximum underbalance when each zone is perforated. Well conditions, economics, and your preferences determine the actual configuration. In some situations, the bottom packer can be run and set on wireline, and then both strings run simultaneously.

Usually the long string is run first, the packer set and tested, and the VannGun® assemblies fired. After clean up, a plug is set in the packer, the tubing pulled, and the dual packer and string run, set, and tested prior to perforating the upper zone.

Dual String with Y-Block

The Halliburton Y-block provides the flexibility to perforate widely separated intervals without the cost of gun spacers and long detonating cord runs. Drilling fluids in the short string are displaced by lighter fluids or nitrogen to provide underbalance.

RetrievableHydraulic-SetDual Packer

Profile Nipple


Model II or Model IIIAssist Firing Head orPressure-ActuatedFiring Head

Dual Phase VannGun®Assembly


Gun Guides

Profile Nipple

Bar Pressure Vent

Model II-D Firing Head

Automatic Tubing Release

VannGun Assembly

RetrievableDual Packer

Halliburton Y-Block


Dual Phase VannGunAssembly

®

Gun Guide


Halliburton Y-Block



Gun Guide


Retrievable Packer

HA

L5

87

3

HA

L5

87

5

Dual Completion Halliburton Y-Block


S

Single-String Selective Completion

Combining the Vann™ Y-block with Halliburton sliding sleeves allows multiple zones to be perforated, tested, and selectively produced through a single string. While the diagram shows a typical completion, the tools can be used to complete multiple zones.

Side Pocket Mandrel

The side pocket mandrel firing head (SPMFH) is designed for well conditions that preclude the use of a pressure-actuated firing head run with a Y-block. The side pocket mandrel firing system is used on single-string, multizone completions, and standard dual completions. A modified model III-D mechanical firing head is attached to the short string side of a side pocket mandrel. The firing head is detonated with a kickover tool run on slickline.

Retrievable Packer

Sliding Sleeve

Y-Block

Hydraulic-Set Packer

Tubing Release


Profile Nipple

Fill Disk


®


VannGun Assembly

Time-DelayFiring HeadH

AL

15

40

6

Dual RetrievablePacker

Sliding Sleeve

Side PocketMandrel

Model II-D or III-DFiring Head

RetrievablePacker

Sliding Sleeve

Y-Block

PermanentPacker

Profile Nipple

Fill Disk

Profile Nipple

ModelIII-DFiring Head

Profile Nipple

KickoverTool

Model II-D or III-DFiring Head

Dual PhaseVannGun Assembly


HA

L8

14

3

Single-Stringelective Completions

Side Pocket Mandrel


Annulus-Fired Systems

Annulus Pressure Firer-Control Line

This string maximizes underbalance pressures—ideal for situations when nitrogen is unavailable or too costly. Tubing runs in dry or with a minimal fluid pad. Annulus pressure firer-control line (APF-C) tools let you fire the guns without pressuring tubing—maintaining maximum underbalance.

Slimhole Annulus Pressure Firer-Internal Control

The operation of the slimhole annulus pressure firer-internal control (APF-IC) system depends on the transfer of annular pressure through the packer down to the APF-IC firing head. This is accomplished through the use of concentric tubing, which eliminates the need for external control line.

BIG JOHN®Jar

Safety Joint


CHAMP®Packer

Fill Disk

Pressure Transfer Control Line

VannGun Assembly®

Collet Assembly

Annulus Pressure FiringHead with Extended MechanicalFiring Head

OMNI™ Valve

BIG JOHN®Jar

Annulus Pressure Transfer Reservoir

Packer

APF-IC Firing Headwith Model II-D orModel III-D Firing Head

VannGun Assembly®

Collet Assembly

Flow Ports

Safety Joint

HA

L5

88

3

HA

L1

54

03

Annulus Pressure Firer-Control Line (APF-C)

Slimhole Annulus Pressure Firer-Internal Control (APF-IC)


Annulus Pressure Crossover Assembly

The annulus pressure crossover assembly (APCA) allows the use of annulus pressure to actuate any one of several firing heads. This assembly is compatible with retrievable packers of all types and sizes.

The APCA creates a pressure chamber above the firing head that is equalized with the pressure in the casing annulus. Once the packer has been set, the pressure on the annulus can be increased to actuate a pressure-actuated firing head. The pressures in the annulus and the tubing can also be manipulated to create the differential pressure necessary to actuate a differential-type firing head. Packer

Ported Sealing Sub


Annulus PressureCrossover Assembly

VannGun Assembly®

HA

L1

05

35



Modular Gun System

The Halliburton modular gun system brings tubing conveyed perforating advantages to monobore completions—without creating flow restrictions.

The system also eliminates the need for—and the cost of—tubing between the guns and packer in conventional completions.

The automatic-release gun hanger is set, then VannGun® assemblies with modular gun connectors attached are run in on wireline and stacked. Surface equipment is installed and tested. Then the guns are fired—causing the automatic-release gun hanger to release and fall into the rathole with all perforating tools, or the expended guns can be removed on wireline.

Modular Gun System

Running/Releasing Tool

Running Stinger

Slickline DeployedMechanical Firing Heador Time-Delay Firing Head

Centralizers

VannGun Assembly®

Modular Gun Skirt

Shooting Stinger

VannGun Assembly

Modular Gun Skirt

Shooting Stinger

VannGun Assembly

Shooting Stinger

Automatic ReleaseGun Hanger

HA

L5

90

7


Enhanced Overbalanced Perforating Solutions

POWR*PERFSM Process

The POWR*PERFSM process uses bauxite to mechanically scour perforations, aiding in damage removal. The system also produces information that can improve stimulation treatment design.

POWR*PERF, a process of Marathon Oil Company, is licensed by Halliburton. POWR*PERF is a service mark/trademark of Marathon Oil Company and licensed by Halliburton.

PerfStim™ System

The PerfStim™ system, an extreme overbalanced perforating system, not only produces cleaner perforations in low-pressure formations, it also initiates fractures in the formation, reducing stimulation costs.

The extreme overbalance—a pressure gradient of at least 1.4 psi/ft (31Kpa/m)—creates a high-pressure surge at the instant of perforation, driving a fluid spear into the formation. The spear removes crush zone damage and initiates fractures in the formation, often creating negative skin factors.

PerfStim™ is a trademark of Oryx Energy Company.Patented by Oryx and licensed by Halliburton.

Tubing

Wellhead Isolation Tool

Radioactive Collar

Nitrogen

Fluid Column

CHAMP IV Packer®

Model KV-II Firing Head

Proppant Carrierwith Punch Charges

VannGun Assembly®

Nitrogen

Fluid Column

Radioactive Collar

CHAMP IV Packer®

Tubing

Vann™ Model KV-IIFiring Head

VannGun Assembly®

HA

L1

53

14

HA

L1

53

87

POWR*PERFSM Process PerfStim™ System


StimTube™ System

The StimTube™ system creates a surge of high-pressure gas at the formation face that cleans up damage, initiates fractures, and removes emulsion blocks from existing perforations. Typical applications include stimulating thin zones with nearby gas or water and selectively stimulating multiple zones without running and setting packers for each zone.

The service can be used in cased holes after perforations have been shot or in openhole. The tool runs on standard Halliburton tubing conveyed perforating strings or wireline.

StimTube is a trademark of Marathon Oil Company.

StimGun™ Tool

The StimGun™ tool generates large volumes of high-pressure gas the instant the guns fire. The gas enters the perforations, breaks through crush-zone damage, and enters and fractures the formation. The system produces cleaner perforations, lowers hydraulic fracturing costs, and improves production.

Slipping a propellant sleeve over a conventional VannGun® assembly before it is run creates the StimGun tool. The pressure and shock wave created when the perforating charges fire ignites the sleeve.

StimGun is a trademark of Marathon Oil Company.

PLS Packer

Firing Head

Centralizer

Firing Head

Fill Disk

Safety Joint

RadioactiveCollar

On/Off Connector

Vent

StimTube™ System

Fast GaugeRecorder

Fast GaugeRecorder

PropellantSleeveover VannGunAssembly

®

RetrievablePacker

Radioactive Mark

HAL

1540

8

HAL

1540

5

StimTube™ System StimGun™ Tool


Sand Control Solutions

Shoot and Pull

Halliburton’s shoot and pull controls underbalance while limiting sand production and surging perforations.

After perforating, the string is pulled from the well. Halliburton’s annulus pressure operated OMNI™ valve provides for reversing out produced fluids, spotting a fluid loss pill across the perforated interval, and circulating the kill fluid without requiring tubing movement.

Shoot and Pull

PR Fas-Fil Valve

RD Valve

Bundler Carrier withElectronic Gauge

BIG JOHN®Jar

RTTS Safety Joint

CHAMP®

Retrievable Packer

Bar Pressure Vent

Model II-D or III-D PressureAssisted Firing Head

VannGun Assembly®

Collet Assembly

Sump Packer

HAL

1540

7


STPP™-GH Single-Trip Perf/Pack System

The STPP™-GH single-trip perf/pack system provides cost-effective, single run completions that combine perforating and frac-packing into a single string. With the STPP-GH system, the guns are detached from the packer before perforating to eliminate impact loads on the packer. After perforating, the auto-release gun hanger mechanism allows the expended guns to drop to the bottom of the well. After the well is perforated, the CHAMP® IV packer is lowered and set below the perforations to complete frac-pack operations. The STPP-GH system provides increased safety as well as economic benefits by combining multiple operations in a single pipe trip. The single-trip system can minimize completion fluid loss, reduce rig cost, and reduce well control risks.

STPP™-GH Single-Trip Perf/Pack System

CHAMP IVPacker

®

ClosingSleeve

Assembly

BlankAssembly

LowerSump Packer

HydraulicRelease

VannGunAssembly

®

Auto ReleaseGun Hanger

VBAFracPac™

Packer

ClosingSleeve

BlankScreen

LowerSumpPackerH

AL88

29


Cobra Pac® Service

The Cobra Pac® service brings together key Halliburton technologies that can help make previously bypassed zones profitable to produce, such as a complete rigless process with electric line, coiled tubing (CT), and perforating solutions to install a vent screen completion.

Ideal zones have these characteristics:

• Completion with 2 7/8-in. and larger tubing

• One to five billion cubic feet reserves or less per zone

• Six to 12 months production life per zone

• Stacked zones, limited reserves, and small fault blocks

Lower zone is isolated by setting a cement retainer or bridge plug on electric line for depth control. The perforating and vent screen assembly is run on CT, and guns are correlated by tagging cement retainer/bridge plug or utilizing DepthProSM

collar locator. Pressure is applied to tubing to fire perforating guns and then guns are lowered to bottom and released from CT with hydraulic release. Sand control treatment is pumped through tubing and then CT is run in the hole to wash the sand off the top of the vent screen.

Cobra Pac® Service

Production Packer

End of Tubing

Vent Screen

Blank

Screen

PressureFiring Head

VannGun Assembly®

Plug BackHA

L1

53

97


Perforate and Squeeze

Single-Trip Block Squeeze DrillGun™ System

The unique Halliburton all-aluminum VannGun® system and brass firing head greatly reduce the costs of block squeeze procedures—especially in highly deviated wells.

The packer is set and perforations shot in the same trip. After pulling the workstring and pumping the squeeze job, the packer and aluminum gun are drilled out.

The system provides another substantial savings. The well is controlled without replacing clear fluids with drilling mud while perforating, so there are no mud disposal problems.

Single-Trip Block Squeeze DrillGun™ System

Radioactive Marker

Setting Tool

Brass Pressure-ActuatedFiring Head

All-AluminumVannGun Assembly

®

EZ Drill SVBSqueeze Packer

®

HA

L5

91

2


Select Fire™ Systems

Halliburton’s unique Select Fire™ system provides unprecedented flexibility. Guns can be configured to fire sequentially top down or bottom up—or in any order. Zones can be isolated for perforating and testing or flow from each new set of perforations can be commingled with flow from earlier perforations. The system provides the following benefits:

• Eliminates the need to kill the well

• Eliminates pulling and re-running the test string after firing each set of guns

• Eliminates the need to re-establish well flow

This sequence on the following page illustrates perforating and testing each zone sequentially from the bottom up and commingling flow from the zones. (If conditions required isolating each zone, the packer would be moved and reset after each zone was shot and tested.)


Annulus PressureCrossover Tool

Packer

Ported Sealing Sub

Third VannGun Assembly®

Third Time-DelayFiring Head

Second Air Chamber

Second Select Fire™ Sub

Second Pressure Isolation Sub

Second VannGun Assembly

Second Time-DelayFiring Head

First Air Chamber

First Select Fire Sub

First Pressure Isolation Sub

First VannGun Assembly

First Time-Delay Firing Head

Control Line Sub

Control Line

HA

L8

19

1


Step 1—Annulus pressure from above the packer enters the crossover tool and is applied to the first (bottom) time-delay firing head. The first Select Fire™ sub keeps pressure from reaching the second firing head. The time delay provides time to bleed off pressure. When the guns detonate, the firing train continues to the Select Fire sub. The sub fires, creating a path to the second firing head. The zone is tested.

Step 2—Annulus pressure is re-applied and travels to the second time delay firing head. The first pressure isolation sub keeps pressure from venting through the first set of perforations. Pressure is released, the gun fires, and the second Select Fire sub fires and opens a path to the third gun. Production from the second zone is commingled with pressure from the first zone for testing.

Step 3—Pressure applied to the annulus passes through the annulus pressure crossover and down the control line to the third time-delay firing head. The second pressure isolation sub keeps pressure from venting through perforations in the first and second zones. Pressure is released, the guns fire, and flow from all three are commingled for testing.

HA

L8

19

1

Step 2Step 1 Step 3


Dual Drillstem Test System

Incorporating components of Halliburton’s innovative Select Fire™ system, this string isolates each zone for perforating and testing.

The Halliburton CHAMP® retrievable packer sets mechanically while tubing pressure sets the top packer. After setting packers, pressuring up on the tubing opens the pressure-operated vent to provide communication below the lower packer. Additional pressure fires the lower set of guns.

After testing, annulus pressure closes the Vann™ circulating valve, isolating the lower zone. Produced fluid is reversed out using the Halliburton OMNI™ valve. Increasing and releasing annulus pressure fires the upper guns.

Dual Drillstem Test System

Annulus Pressure Crossover

Hydraulic-Set Packer

Control Line


Select Fire™ Sub


Select Fire Sub


VannGun Assembly®


CHAMP®

Packer




Circulating Valve

VannGun Assembly

HA

L5

90

8


Live Well Perforating

Ratchet Connector

The innovative design behind the Halliburton ratchet connector significantly reduces the cost of using perforating techniques in live wells.

Benefits

• Delivers the advantages of live well perforating with no costly kill fluids; no kill-fluid caused by formation damage; formation back-surge pressures clean perforations

• Connection time of approximately 20 minutes or less per VannGun® assembly—a fraction of the time required by other systems

• Halliburton hydraulic workover unit runs tools, freeing the drilling rig.

• Uses standard blowout preventer (BOP) stacks with no need for special ram assemblies

• Maintains positive pressure control—does not compromise pressure control systems engineered into Halliburton hydraulic workover units—since at least one BOP ram closes during every running in and retrieval step

• Eliminates the risk of damaging producing zones with kill fluids when reperforating producing wells

Ratchet Connectors

The following outlines what occurs when VannGun assemblies are run under pressure with the Halliburton ratchet connector.

Step 1—Closing the seal slip rams around the ratchet connector seal sub hangs the first VannGun section in the BOP stack. The blind rams are closed.

Step 2—The second VannGun section, with the ratchet section of the ratchet connector attached, is stripped through the open stripper rams (not shown).

Step 3—Once the gun section passes, the stripper rams are closed and the blind ram opened. The second gun section is lowered until the two ratchet connector sections meet. Turning to the left activates the ratchet, connecting the two sections.

Step 4—The guns are lowered until the ratchet connector seal sub atop the second VannGun section is opposite the seal ram. After closing the ram, turning to the right releases the running tool. The running tool is raised above the blind ram, which is then closed, and the stripper ram opened. The next VannGun section is attached and the procedure repeated.

The procedure is reversed when retrieving the perforating assembly.

AutoLatch™ Release Gun Connector

The Halliburton AutoLatch™ release gun connector literally latches VannGun sections together in the BOP stack as they run in. No rotation is required to connect the guns, so guns can be run and retrieved on coiled tubing or even wireline. Connections make up in a fraction of the time required by conventional snubbing systems.

Benefits

• Delivers the advantages of live well perforating with no kill fluids, no kill-fluid caused formation damage, formation back-surge pressures clean perforations—without the cost of a drilling rig

• Halliburton coiled tubing or wireline units run and retrieve guns.

• Uses standard BOP stacks—special ram assemblies not required

• Maintains positive pressure control—at least one BOP ram closed during every running in and retrieval step.

• Perforates new zones in producing wells without kill fluids, eliminating the risk of damaging currently producing zones

SecondVannGunSection

®

Blind Ram

Ratchet ConnectorSeal Slip Ram

Ratchet ConnectorSeal Sub

FirstVannGunSection

HA

L5

80

9


Operation-AutoLatch™ Connector

The AutoLatch™ release gun connector consists mainly of the stinger and latching/releasing assemblies. To operate, the stinger assembly is threaded into the top of the first VannGun® section, and the latching/releasing assembly is threaded into the bottom of the second VannGun section.

The first VannGun section is run into the well and set in the seal/slip rams. (There is a seal area on the stinger for the rams.) The running tool is released from the first VannGun section and then pulled from the BOP stack.

The second VannGun section is then run into the well and set over the stinger. Weight is set down on the latching/releasing assembly to shear the screws and to latch the collet fingers onto the stinger. Once the two VannGun sections are latched, the seal/slip rams are opened and the two VannGun sections are lowered into the well until the seal area on the stinger assembly (at the top of the second perforating gun section) is positioned in the seal/slip rams, which are then closed on the stinger. The running tool is released, and it is pulled out of the well.

This procedure is repeated until all VannGun sections are run into the well. Refer to the operating manual for procedures when running and retrieving under pressure, or when using coiled tubing, hydraulic workover, or wireline.

Operation-Ratchet Connector

The ratchet connector connects with left-hand rotation. Shear pins prevent disconnecting when rotating to the right.

The connection sequence begins with one VannGun assembly hung in the BOP stack with the seal slip rams and blind rams closed. The second VannGun assembly, with the ratchet made up at the bottom, is stripped through the open stripper ram. Once the connector and VannGun assemblies are past the stripper rams, they are closed and the blind rams opened. When the tool components meet, rotating to the left activates the ratchet, joining the two VannGun sections. The string is lowered until the seal area of the connector is next to the seal/slip ram area. The ram is closed. Left-hand rotation shears the brass pins and allows the tool to disconnect. The running tool is lifted above the blind rams, which are then closed.

To retrieve the perforating assembly, the connection sequence is reversed.


Operation-Ratchet Connector

BlindRam

PipeRamSeal/Slip

Ram

BlankRam

HA

L5

79

6

Coiled Tubing orJointed Pipe

Pressure-ActuatedFiring Head

Third VannGunSection

®

AutoLatch™ ReleaseGun Connector

Second VannGunSection

AutoLatch ReleaseGun Connector

First VannGunSection

HA

L11

75

3



Each VannGun® section is connected to the AutoLatch™ running tool on the surface and run into the BOP through the stripper rams (not shown).

The AutoLatch running tool is pulled out of the BOP stack, leaving the stinger and VannGun section suspended by the seal/slip rams.

The assembly is lowered until the seal area of the AutoLatch stinger is opposite the seal/slip rams. The seal/slip rams are closed to suspend the first VannGun section and stinger assembly in the BOP stack. Closing the pipe rams compresses stop-release pads on the AutoLatch running tool, unlatching the tool.

Once the AutoLatch running tool is above the blind rams, the rams are closed.

AutoLatchStingerAssembly

AutoLatch™RunningTool

FirstVannGunAssembly

®

HA

L5

79

7



®


HA

L5

79

9




®

HA

L5

79

8

Blind RamAssembly

AutoLatch™StingerAssembly


®

HA

L5

80

0


The AutoLatch™ skirt assembly is made up on the bottom of the second VannGun® section. The assembly is lowered onto the AutoLatch stinger atop the first VannGun section.

Isolation Sub-Assembly

The isolation sub-assembly allows the customer the capability to complete or recomplete the well without killing it. The well can be producing before, during, and after the guns are deployed in or out of the well.

The AutoLatch skirt on the second VannGun section sits down on and latches to the AutoLatch stinger atop the first VannGun section, and the cycle begins again.

Guns are retrieved by reversing running-in procedures.

AutoLatch™SkirtAssembly



®

HA

L5

80

1

Lubricator

Upper Gun

Snubbing Connector

Lower Gun

BOP Stack

HA

L1

23

26

SecondVannGunAssembly

®

AutoLatch™Skirt

Assembly



HA

L5

80

2


Downhole Pump Completions

This string not only provides the advantages of underbalanced perforating in rod-pumped wells, it also keeps fluids away from sensitive formations.

VannGun® assemblies run in on a standard rod-pump production string. Pumping the well down creates the underbalance and initiates the Vann™ pressure differential firing head.

Downhole Pump Completions

Sucker Rod

Tubing Anchor

Sucker Rod Pump

Pump SeatingNipple

Pressure Transferand Bypass

Differential PressureFiring Head

VannGun Assembly®

HA

L1

53

53


Coiled Tubing Perforating

Coiled tubing is another method used in the industry to deploy perforating guns and other tools into a well. The firing mechanisms used are hydraulically operated. The

firing heads are the ball drop actuator firing head, which is also available with a swivel; and the pressure-actuated firing heads such as TDF, model K, KV-II, etc.

Coiled Tubing Conveyed Bridge Plug with Pressure Firing Head

Coiled Tubing Conveyed Bridge Plug with Pressure Firing Head

Bridge Plug

Coiled Tubing

Dual FlapperCheck Valve

HydraulicDisconnect

PressureRelief Sub

KV-IIFiring Head

Setting Tool

Bridge Plug

Coiled Tubing

HA

L1

54

09


Coiled Tubing Conveyed Pipe Cutter with Pressure Firing Head

Cutter

Packer

Sealbore

Nipple

Re-entry

Coiled Tubing

Tubing


HydraulicDisconnect

PerforatedNipple

PressureFiring Head

SeveredPipe

HA

L1

54

10

Coiled Tubing Conveyed Pipe Cutter with Pressure Firing Head


Coiled Tubing Conveyed Perforating with Pressure Isolation (Closed System)

Coiled Tubing Conveyed Perforating (Open System)

Model KV-IIFiring Head

Coiled Tubing

Connector


HydraulicDisconnect

Pressure ReliefSub

PressureIsolation Device

VannGunAssembly

®

PressureIsolation Device

HA

L1

54

11

Coiled Tubing Conveyed Perforating with Pressure Isolation

(Closed System)

Coiled Tubing

Connector


HydraulicDisconnect

PerforatedNipple

PressureFiring Head

HA

L1

54

12

Coiled Tubing Conveyed Perforating (Open System)


Van

nG

un

® A

ssemblies

VannGun® AssembliesThe heart of Halliburton’s VannSystem® service is the VannGun® assembly. The VannGun assembly uses bi-directional boosters, nonlead azide explosives, specialized connectors and inserts, and high velocity-low shrink detonating cord.

All these, as well as premium quality gun material, are manufactured to Halliburton’s proprietary specifications. The primary design factors for these components are safety and reliability. All VannGun assemblies incorporate machined scallops.

This helps to optimize charge performance and prevents casing damage from perforating exit hole burrs. Additionally, shot phasing is designed to maintain the integrity and collapse resistance of the casing after perforating.

4 5/8 in. 5 SPF60° Phasing

3 3/8 in. 6 SPF 60° Phasing

4 5/8 in. 12 SPF30°/150° Phasing

7 in. 14 SPF138° Phasing BH/SH

HAL

1540

4

VannGun® Assemblies 4-1

History of Perforation Techniques

Original cased hole completions utilized various mechanical tools to gouge or penetrate casing to establish reservoir to wellbore communication. Mechanical tool use at the time was very inefficient and time consuming especially when longer pay zones were encountered.

In 1926, bullet perforators were patented and by the 1930s had gained widespread acceptance. Bullet perforators used a propellant-driven bullet that would penetrate the casing, cement, and formation. The obvious drawback was the lodging of the bullet or projectile in the perforation tunnel, which restricted reservoir fluid flow into the wellbore. Another drawback was that the penetration depth achieved with a bullet perforator was quite short, usually only a few inches at best. Bullet perforators are rarely used today except in cases where uniform casing hole size is required for utilizing ball sealers for acid diversion.

Shaped charges or jet perforators were introduced to the oilfield in the late 1940s. Design and utilization of these charges is based on the same principles as the steel armored tank penetrating bazooka technology from World War II. Today, shaped charges account for more than 95% of the cased and perforated completions around the world. The simple design of the shaped charge features primary components that include a charge case, explosive powder, and liner. The shaped charge liner can be designed to either create a jet that makes a small casing exit hole with deep formation penetration or a large casing exit hole with minimal formation penetration. Shaped charges are generically classified as either deep penetrating (DP) or big hole (BH).

In the 1950s, special through-tubing gun systems (small OD hollow steel carriers and expendable strip guns) were developed. The through-tubing gun systems offered great advantages over the casing gun technology of the time which required perforating be performed in an overbalanced condition. The through-tubing gun systems allowed operators to run the completion and nipple up a tree for well control and then establish an underbalance prior to perforating. This led to better perforation cleanup and well productivity. By the 1970s, Vann Tool Company had perfected the Tubing Conveyed Perforating (TCP) technique, allowing operators to convey unlimited lengths of perforating guns and safely creating much higher underbalance pressures than were possible with through-tubing gun systems. TCP guns systems (using percussion-

type detonators) provided a much safer alternative to through-tubing gun systems (with electrical type detonators) available at the time and also enabled operators to perforate the entire pay zone with the given underbalanced condition for optimum well productivity.

In the 1990s, ORYX Energy Company developed the PerfStim™ process which used TCP applications where the wellbore is overpressured above the fracture gradient prior to the perforating event to promote fracturing in the near-wellbore region to improve well productivity. Marathon Oil Company improved on this process, by introducing the POWR*PERFSM process, which used proppant carriers above the perforating guns. The proppant carriers are designed to release proppant or any other scouring agent into the flow stream after the guns are detonated, and the nitrogen / fluid cushion is injected into the perforations. In 1997, Marathon Oil Company also introduced the StimGun™ assembly, which combines conventional TCP gun systems with a propellant energy source. The TCP gun is actuated by conventional means, and then the propellant is ignited to generate CO2 gas at pressures above the fracture gradient to create small narrow fractures in the near-wellbore region.

Hydraulic perforators were originally introduced in the 1960s as a means to penetrate the casing by pumping high-pressure fluids with an abrasive agent (sand) to abrade the casing, cement, and formation. Hydraulic perforating is very slow and can be expensive since only a few holes are created simultaneously. In recent years, this technique has gained some renewed interest especially as a pre-cursor to planned limited entry hydraulic fracturing where only a few holes are required in the casing to pump the treatment.

POWR*PERF, a process of Marathon Oil Company, is licensed by Halliburton. POWR*PERF is a service mark/trademark of Marathon Oil Company and licensed by Halliburton. StimGun™ is a trademark of Marathon Oil Company and is licensed by Halliburton.PerfStim™ is a trademark of Oryx Energy Company.Patented by Oryx and licensed by Halliburton

Year Perforation Technique

Mechanical Tools

1930s Bullet Perforators

1940s Shaped Charges

1950s Through-Tubing Guns

1970s Tubing Conveyed Perforating (TCP)

1990s Extreme Overbalance (EOB) Perforating

1997 Extreme Overbalance with StimGun™ Assembly

1960s and 1990s Hydraulic Perforators

4-2 VannGun® Assemblies

Deep Penetrating Charges

Deep penetrating type charges have a generally cone shaped liner geometry that produces a thin, faster-moving jet. Formation penetration is relatively deep with a somewhat small exit hole size in the casing. Deep penetrating type charges are typically utilized in natural completions, which do not require sand control or gravel packing.

DP shaped charges consist of liners that are formed by compressing various blends of powdered metal. Powdered metal liners tend to break up during jet formation and tunnel creation, leaving minimal residual debris from the liner itself after the perforation event.

DP Shaped Charge Liners

DP charge case material is typically classified as steel or zinc-based with the zinc termed as low debris (LD). The majority of debris associated with the shaped charge is derived from the charge case material.

Steel charge cases tend to fragment into larger steel particles that are likely to remain inside of the gun carrier because of the small exit hole in the gun scallop. Zinc charge cases, however, will basically disintegrate into a powder-like substance capable of exiting the gun scallops completely.

DP Shaped Charge Case and Liner

Zinc Charge Case and Debris

Steel Charge Case and Debris

Big Hole Vs. Deep Penetrator Charge Liners

Halliburton Shaped Charge TerminologyDeep Penetrating Types

DP Deep Penetrating

SDP Super-Deep Penetrating

DP/LD Deep Penetrating/Low Debris

Millennium™ Charge Trade Name Premium DP

Dominator® Charge Trade Name Special DP

Big Hole Types

BH Big Hole

BH/LD Big Hole/Low Debris

SH Super Hole

SH/LD Super Hole/Low Debris

Mirage® Charge Trade Name Special BH/LD

Excalibur ChargeTrade Name Hybrid BH/DP for

Dual Casing Applications

HAL

1636

3

HAL

1636

5

HAL

1603

5

HAL

1603

2

HAL

1636

4


When introduced, the Millennium™ line of DP shaped charges was the industry leading performer in API Section I test conditions for the most commonly used gun systems. Millennium shaped charges were optimized for performance by improving jet tip velocity, which was accomplished through tighter tolerances on liner specifications, optimization of powdered metal composition, and overall improvements in quality assurance during the manufacturing process.

The Dominator® line of DP shaped charges are special charges optimized for actual shaped charge performance under the prevailing completion and reservoir conditions. Dominator shaped charge development takes place using the Perforation Flow Laboratory facility. The Perforation Flow Laboratory allows shaped charges to be fired with under or overbalanced well conditions in actual formation samples with a given effective stress condition applied. The Perforation Flow Laboratory also has the benefit allowing post-perforation flow or injection into the formation sample to assess perforation efficiency or productivity.

Dominator shaped charge development typically results in improved formation penetration on the order of 15 to 20% over conventional DP charges designed for API Section I performance. To evaluate if your specific completion and reservoir conditions warrant a Dominator shaped charge approach, please contact engineering for an assessment.

Big Hole Shaped Charges

BH shaped charges consist of parabolic or hemispherical shaped liners that produce a slower-moving jet. Formation penetration is typically very shallow with a large exit hole casing size. BH type charges are typically utilized on completions that require some form of sand control (frac pack, high-rate water pack, gravel pack, etc.) and are designed to yield the maximum shot density or total flow area. Gun clearance, the annular gap between the gun and casing ID, is especially important for jet development with BH charges; therefore, gun centralization is usually recommended. Failure to centralize BH gun systems can result in significant loss of shaped charge performance as shown in the illustration below where eccentered guns result in a total flow area reduction of 30%.

Entrance Hole Diameters for Centralized Versus Non-Centralized Cases

HAL

1595

6

HAL

1595

7

Actual charge performance in formation core samples comparing standard DP charge on left vs the Dominator®

charge on the right.

.91

.83

.79

.72

.79

.91

.87.85

.89

.71

30°

.80

.89

.95

.95

.88

.96

.96

.91

.92

.87

.97

.95

.88

.95

Area for Centralized Gunis 25% to 30% Higher

HAL

1626

9


Similar to DP type charges, BH shaped charges utilize either steel or zinc (LD) charge case material. BH shaped charge liners are formed by pressing sheet metal into the desired liner shape. Original BH shaped charge liners were formed with copper as the base material. Although copper provided good ballistic characteristics, it also produced undesirable liner debris or slugs.

To compensate for the undesirable slug formed with copper liners, other metallurgy was developed to produce a solution that would eliminate the copper debris issue. Today, virtually all conventional BH or Super Hole (SH) charges utilize special alloy liners that are designed to fragment into small pieces, and thus are significantly less likely to create debris problems during the well completion.

The Mirage® line of BH shaped charges was introduced as an improved low debris system. The Mirage line provides more of a total perforating system debris reduction solution. With the Mirage line, gun debris associated with all components of the perforating assembly is reduced.

Origins of Gun System Debris

Initial (Copper) 7-in. BH Liner Technology

Latest (Mirage®) 7-in. BH Liner Technology

Current (Brass) 7-in. BH Liner Technology

HAL

1636

1H

AL16

360

HAL

1636

6

Charge

ChargeHolder Centralizer

Rubber Pad End Alignment

HAL

1627

6


Previous BH guns systems required that the shaped charges be positioned and retained in the charge tube holder using bend tabs. The bend tab is a significant source of gun debris because of the metal slivers generated during gun detonation.

The improved Mirage® system incorporates a new twist lock feature in the charge tube holder, eliminating the debris associated with the bend tabs.

In addition to metallurgical considerations, the geometry of the Mirage shaped charge liner is carefully controlled during the manufacturing process such that those portions of the liner that might contribute to slug creation are removed. This process results in a charge liner with a controlled geometry liner (CGL).

Mirage® Super Hole Perforator

“Thick” regioncontrolled toreduce debris

“Thinned” regionafter forming

HAL

1627

0

Typical Charge Tube Design

Improved Mirage® Charge Twist Lock Tube Design

Charge Tube Debris

HAL

1626

6H

AL16

275

HAL

1627

4


The LD zinc charge cases with the Mirage® system have been optimized to reduce the particle size distribution as shown below.

Sieve Analysis Charge Case Material

Case Debris Comparison (One Charge)

0.0

10.0

20.0

30.0

40.0

50.0

60.0

70.0

> 0.500 > 0.375 > 0.250 > 0.187 > 0.094 > 0.066 > 0.033 > 0.011 <.011

Particle Size (in.)

Ma

ss

Re

tain

ed

(g)

Mirage Case Debris

LD Zinc Case Debris

Steel Case Debris

HAL

1626

7



Maxim™ Shaped Charges

Well completion in unconsolidated formations generally requires some form of sand control or gravel packing for flow assurance. For a cased and perforated sand control completion, the perforating strategy typically calls for perforations with the largest possible exit hole in the casing with as high a shot density (spf) as possible. The large casing exit hole improves the likelihood of placing sand or gravel into the perforation tunnel and the higher spf increases the effective flow area resulting in lower pressure drop across the completion during production.

As completion targets in deep water environments go deeper, drilling challenges are compounded forcing operators in many cases to set the casing shoe point higher than planned in order to safely reach deeper primary targets. Unfortunately, this scenario results in secondary pay zones that have multiple strings of casing across portions or the entire length of the pay zone. This situation presents a serious technical challenge because the typical big-hole (BH) perforating system cannot efficiently penetrate multiple casing strings and still produce an adequate casing exit hole. The results utilizing conventional BH perforating systems in the past yielded a large exit hole in the first casing string and a very small exit hole in the second casing string with minimal formation penetration.

Shaped charge design engineers at Halliburton's Jet Research Center (JRC) have unleashed the power of Maxim™ shaped charges by utilizing hydro-code modeling software and flash x-ray imaging to develop a proprietary shaped charge liner that optimizes the casing exit-hole size when penetrating multiple casing strings.

The effectiveness of the new Maxim shaped charge concept was demonstrated with the development of a 5-in. 8 spf 47 g charge for a completion scenario with 7-5/8-in. 47.1 #/ft P-110 and 9-5/8-in. 47 #/ft P-110 casing. A standard 5-in. 12 spf 28 gram BH gun system was tested under the completion configuration described resulting in a casing exit-hole of 0.28-in. The newly developed Maxim perforating system resulted in a casing exit-hole size of 0.66-in. with an

impressive formation penetration of 6.0-in. These results show a significant 136% improvement in casing exit-hole size and 270% improvement in flow area on a per foot basis.

Expanding

Case Fragments

Stretching Jet

Jet Tip

Rearmost Portion

of Jet

HA

L1

59

55

Maxim™ Dual String Technology

Existing Dual String Technology

HAL

1636

2

HAL

1635

9

Flash x-ray and hydro-code simulation of a shaped charge during detonation sequence.

Maxim™ Charge Performance Data

Charge Part No. Gun OD SPF

Explosive Load Inner Casing Exit Hole Outer Casing Exit Hole Penetration*

101350449 5.00 8 47 7 5/8 47.1# P-110 0.75 9 5/8 47 P-110 0.66 6.00

101357518 5.75 10 56.5 8 5/8 60.8# P-110 0.78 11 3/4 65# P-110 0.63 7.50

101357518 7.00 14 56.5 9 5/8 473 lL-80 0.61 13 3/8 72# P-110 0.68 8.77

*Penetration is in cement measured from the OD of the outer casing.

VannGun® Assemblies 1 9/16 in. to 7 in. and 4 SPF to 21 SPF

7.00"

6.50"

6.00"

5.75"

5.125"

5.00"

4.625"

4.25"

4.00"

3.125"

2.875"

2.50"

2.75"

2.00"

1.563”

3.375"

4.50"

4.75"


VannGun® Phasing and Shot Patterns*

0° Phasing 4 and 5 SPF

6"

6"

12"

0º 180º 360º

5 SPF

6"

6"

12"

0º 180º 360º

4 SPF

HAL

1059

0

60° Phasing 4, 5, and 6 SPF

6"

6"

12"

0º 60º 120º 180º 240° 300º 360º

4 SPF

6"

6"

12"

5 SPF

0º 60º 120º 180º 240° 300º 360º

6"

6"

12"

0º 60º 120º 180º 240° 300º 360º

6 SPF

HAL

1597

8

*Other shot densities and phasings are available upon request.


90° Phasing 4 SPF

6"

6"

12"

0º 90º 180º 270° 360º

4 SPF

HAL

1598

1

180° Phasing 4 and 8 SPF

6"

6"

12"

0º 180º 360º

4 SPF

6"

6"

12"

0º 180º 360º

8 SPF

HAL

1598

2


60° Phasing 6 SPF Two Planes

6"

6"

12"

0º 45º 90º 135º 180º 225° 270º 315º 360º

6 SPF

HAL

1535

6

45°/135° Phasing 5, 6, 8, 12, and 18 SPF

6"

6"

12"

0º 45º 90º 135º 180º 225° 270º 315º 360º

5 SPF

6"

6"

12"

0º 45º 90º 135º 180º 225° 270º 315º 360º

6 SPF

6"

6"

12"

0º 45º 90º 135º 180º 225° 270º 315º 360º

8 SPF

6"

6"

12"

0º 102.9° 205.7° 308.6°

12 SPF

51.4° 154.3° 257.1° 360º

6"

6"

12"

0º 45º 90º 135º 180º 225° 270º 315º 360º

18 SPF

HAL

1535

5


140°/160° Phasing 11 SPF

6"

6"

12"

11 SPF

100º

110º 250°

260°180° 360°0º

HAL

1598

3

51.4°/154.3° Phasing 12 SPF

6"

6"

12"

0º 102.9° 205.7° 308.6°

12 SPF

51.4° 154.3° 257.1° 360º

HAL

1535

7

30°/150° Phasing 12 SPF

6"

6"

12"

12 SPF

0º 60° 120º 180º 240° 300º 360°

30º 90º 150° 210° 270º 330°

HAL

1535

4


25.7°/128.5° Phasing 14 SPF

6"

6"

12"

0º 51º 103º 154º 206º 257° 309º 360º

14 SPF

26º 77º 129º 180º 231º 283° 334º

HAL

1599

3

60°/120° Phasing 18 and 21 SPF

6"

6"

12"

18 SPF

0º 60º 120º 180º 240° 300º 360º

6"

6"

12"

21 SPF

0º 60º 120º 180º 240° 300º 360º

HAL

1598

4

138° Phasing 14 SPF

6"

6"

12"

0º 45º 90º 135º 180º 225° 270º 315º 360º

14 SPF

HAL

1598

5


Tensile ratings on the following tables are based on the box x pin connection.

1 9/16-in. Premium VannGun® Assemblies

Charge Part No.

Explosive Type Charge Type SPF Phasing

Collapse Pressurepsi (bars)

Tensile Strengthlb (kg)

Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)

100157028 HMX Millennium™

4

0°60°90°180°

20,000(1379)

70,000(31 746)

4 spf Millennium4 (1.22) 21 (9) 17 (8)7 (2.13) 31 (14) 24 (11)

101210199 HMX BH11 (3.35) 46 (21) 34 (15)15 (4.57) 60 (27) 44 (20)21 (6.40) 81 (37) 59 (27)

100157028 HMX Millennium 6 60° 20,000(1379)

70,000(31 746)

6 spf Millennium4 (1.22) 21 (10) 17 (8)7 (2.13) 32 (14) 24 (11)11 (3.35) 48 (22) 34 (15)15 (4.57) 63 (28) 44 (20)21 (6.40) 85 (39) 59 (27)

2-in. Premium VannGun® Assemblies

Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)


4

0°60°90°

180°

20,000 (1379)

77,000 (34 921)

4 spf Millennium100008017 HMX SDP 4 (1.22) 28 (13) 23 (10)

100157018 HNS DP7 (2.13) 44 (20) 35 (16)11 (3.35) 66 (30) 51 (23)

101206246 HMX BH15 (4.57) 87 (39) 63 (29)21 (6.40) 120 (54) 92 (42)

101208224 HMX Millennium

6 60° 20,000 (1379)

77,000 (34 921)

6 spf Millennium100008017 HMX SDP 4 (1.22) 28 (13) 23 (10)

100157018 HNS DP7 (2.13) 44 (20) 35 (16)11 (3.35) 66 (30) 51 (23)

101206246 HMX BH15 (4.57) 87 (39) 63 (29)21 (6.40) 120 (54) 92 (42)



Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)


4

0°60°90°180°

20,000 (1379)

121,000 (54 875)

4 spf Millennium

101332418 HMX SDP4 (1.22) 43 (20) 34 (15)7 (2.13) 67 (30) 52 (24)

101244923 HNS DP11 (3.35) 98 (44) 75 (34)15 (4.57) 129 (59) 98 (44)21 (6.40) 176 (80) 133 (60)

101206251 HMX Millennium

6 60° 20,000 (1379)

121,000 (54 875)

6 spf Millennium4 (1.22) 45 (20) 34 (15)

101332418 HMX SDP7 (2.13) 70 (32) 52 (24)11 (3.35) 104 (47) 75 (34)

101244923 HNS DP15 (4.57) 133 (60) 98 (44)21 (6.4) 189 (86) 133 (60)


Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)


6 60° Two Row 20,000(1379)

134,000 (60 771)

6 spf SDP and Millennium100157026 RDX SDP

4 (1.22) 59 (27) 50 (23)100010399 HMX SDP101251723 HNS SDP 8 (2.44) 102 (46) 82 (37)101318485 HNS Millennium 11 (3.35) 134 (61) 105 (48)101206793 RDX BH 16 (4.88) 183 (83) 145 (66)101270158 HMX BH 22 (6.71) 252 (114) 193 (88)101233817 HMX Millennium

6 60° 22,000 (1517)

134,000 (60 771)

100157026 RDX SDP100010399 HMX SDP101251723 HNS SDP101318485 HNS Millennium101206793 RDX BH101270158 HMX BH



Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)


6 60° 22,000 (1517)

142,000 (64 399)

6 spf Millennium4 (1.22) 62 (28) 54 (24)

101414743 HMX Dominator®8 (2.44) 106 (48) 86 (39)11 (3.35) 138 (63) 110 (50)

101388407 HNS Millennium16 (4.88) 186 (84) 150 (68)22 (6.71) 258 (117) 198 (90)

2 7/8-in. Heavy Wall Premium VannGun® Assemblies

Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)


6 60° 25,000(1724)

142,000 (64 399)

6 spf Millennium Gas Gun4 (1.22) 64 (29) 55 (25)8 (2.44) 112 (51) 92 (42)

101318485 HNS Millennium11 (3.35) 148 (67) 120 (54)16 (4.88) 204 (93) 166 (75)22 (6.71) 281 (127) 221 (100)



Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)

101320459 RDX DP

460° 90° 180°

25,000(1724)

238,000(107 937)

4 spf DP4 (1.22) 86 (39) 77 (35)8 (2.44) 144 (65) 125 (57)

100008014 RDX SDP11 (3.35) 187 (85) 160 (73)16 (4.88) 256 (116) 219 (99)

101293450 RDX SDP/LD22 (6.71) 345 (157) 290 (132)

4 spf SDP and Millennium

101233819 HMX Millennium™4 (1.22) 89 (40) 77 (35)8 (2.44) 149 (68) 125 (57)

101265876 HNS Millennium11 (3.35) 195 (88) 160 (73)16 (4.88) 268 (121) 219 (99)22 (6.71) 361 (164) 290 (132)

101320459 RDX DP

6 60° 25,000(1724)

238,000(107 955)

6 spf SDP and Millennium100008014 RDX SDP101293450 RDX SDP/LD 4 (1.22) 92 (42) 77 (35)101233819 HMX Millennium 8 (2.44) 158 (72) 125 (57)101309223 HMX Dominator® 11 (3.35) 207 (94) 160 (73)101265876 HNS Millennium 16 (4.88) 287 (130) 219 (99)100005321 RDX BH

22 (6.71) 388 (176) 290 (132)100157017 HMX BH101320459 RDX DP

6 60° Two Row

23,000(1586)

238,000(107 955)

100008014 RDX SDP101293450 RDX SDP/LD101233819 HMX Millennium101309223 HMX Dominator101265876 HNS Millennium100005321 RDX BH100157017 HMX BH

100008251 RDX BH

12 30°/150° OMNI™

23,000(1586)

238,000 (107 955)

12 spf BH4 (1.22) 89 (40) 77 (35) 8 (2.44) 150 (68) 125 (57)

100005312 HMX BH11 (3.35) 197 (88) 160 (73)16 (4.88) 271 (123) 219 (99)22 (6.71) 365 (166) 290 (132)



Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)

100005322 RDX DP

4 60°90°

20,000 (1379)

278,000(126 077)

4 spf DP4 (1.22) 107 (49) 99 (45)

100005327 HMX DP8 (2.44) 173 (78) 155 (70)

11 (3.35) 223 (101) 197 (89)

101332806 HNS DP16 (4.88) 297 (135) 267 (121)

22 (6.71) 404 (183) 351 (159)

100008014 RDX SDP4 spf SDP

4 (1.22) 110 (50) 99 (45)

101293450 RDX SDP/LD8 (2.44) 179 (81) 155 (70)

11 (3.35) 230 (104) 197 (89)

100008249 HMX SDP16 (4.88) 309 (140) 267 (121)

22 (6.71) 420 (191) 351 (159)

100005322 RDX DP

6 60° 20,000 (1379)

278,000(126 077)

6 spf DP4 (1.22) 111 (50) 99 (45)

100005327 HMX DP8 (2.44) 180 (82) 155 (70)

11 (3.35) 233 (106) 197 (89)

101332806 HNS DP16 (4.88) 319 (144) 267 (121)

22 (6.71) 424 (192) 351 (159)

100008014 RDX SDP6 spf SDP

4 (1.22) 114 (52) 99 (45)

101293450 RDX SDP/LD8 (2.44) 189 (86) 155 (70)

11 (3.35) 244 (111) 197 (89)

100008249 HMX SDP16 (4.88) 336 (152) 267 (121)

22 (6.71) 448 (203) 351 (159)



Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)


5 60° 20,000 (1379)

414,000(187 755)

5 spf 39 g Millennium4 (1.22) 156 (71) 135 (61)

8 (2.44) 257 (117) 208 (94)

101287306 HNS Millennium

11 (3.35) 333 (151) 265 (120)

16 (4.88) 447 (203) 357 (162)

22 (6.71) 611 (277) 469 (213)

100005322 RDX DP

6 60° 20,000 (1379)

414,000(187 755)

6 spf 32 g DP100005327 HMX DP 4 (1.22) 147 (67) 134 (61)

101332806 HNS DP 8 (2.44) 235 (107) 207 (94)

100008014 RDX SDP 11 (3.35) 301 (137) 262 (119)

101293450 RDX SDP/LD 16 (4.88) 405 (184) 354 (161)

100008249 HMX SDP 22 (6.71) 544 (247) 464 (210)

100005311 RDX SH

8 45°/135° 20,000 (1379)

414,000(187 755)

8 spf SH4 (1.22) 151 (69) 134 (61)

101228756 RDX SH/LD8 (2.44) 245 (111) 207 (94)

11 (3.35) 316 (143) 262 (119)

100156995 HMX SH 16 (4.88) 420 (191) 353 (160)

101233690 HMX SH/LD 22 (6.71) 574 (260) 462 (210)



Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)

100005319 RDX BH

11 140°/160° 16,000(1103)

414,000(187 755)

11 spf BH100005326 RDX BH/LD 4 (1.22) 153 (69) 129 (59)100157006 HMX BH 8 (2.44) 252 (114) 197 (89)120038060 HMX BH/LD 11 (3.35) 326 (148) 248 (112)100005324 RDX DP

16 (4.88) 438 (199) 334 (151)100014352 HMX DP101210674 HMX Millennium™

22 (6.71) 600 (272) 436 (198)101343830 HNS DP100005324 RDX DP

12 30°/150° OMNI™

20,000(1379)

414,000(187 755)

12 spf Millennium100005325 RDX DP/LD 4 (1.22) 158 (72) 127 (58)100014352 HMX DP 8 (2.44) 262 (119) 194 (88)100005340 HMX DP/LD 11 (3.35) 340 (154) 244 (111)101210674 HMX Millennium 16 (4.88) 459 (208) 327 (148)101343830 HNS DP 22 (6.71) 626 (284) 427 (194)100005319 RDX BH 12 spf BH100005326 RDX BH/LD 4 (1.22) 154 (70) 127 (58)100157006 HMX BH 8 (2.44) 254 (115) 194 (88)120038060 HMX BH/LD 11 (3.35) 328 (149) 244 (111)

100005311 RDX SH16 (4.88) 442 (200) 327 (148)22 (6.71) 602 (273) 427 (194)

101228756 RDX SH/LD12 spf SH

4 (1.22) 150 (68) 127 (58)

100156995 HMX SH8 (2.44) 245 (111) 194 (88)11 (3.35) 315 (143) 244 (111)

101233690 HMX SH/LD16 (4.88) 422 (191) 327 (148)22 (6.71) 575 (261) 427 (194)

100005311 RDX SH

14 25.7°/128.5° 20,000(1379)

414,000(187 755)

14 spf SH4 (1.22) 150 (68) 124 (56)8 (2.44) 244 (111) 188 (85)

100156995 HMX SH11 (3.35) 315 (143) 235 (107)16 (4.88) 422 (192) 314 (142)22 (6.71) 575 (261) 410 (186)

100156990 RDX BH

18 45°/135° 18,000(1241)

414,000(187 755)

18 spf 4 (1.22) 139 (63) 118 (54)8 (2.44) 222 (101) 176 (80)

100157005 HMX DP11 (3.35) 285 (129) 219 (99)16 (4.88) 379 (172) 291 (132)22 (6.71) 513 (233) 378 (171)



Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)

100005324 RDX DP

12 30°/150° OMNI™

24,000(1655)

516,000(234 014)

12 spf BH4 (1.22) 169 (77) 144 (65)

100005325 RDX DP/LD8 (2.44) 284 (129) 228 (103)

11 (3.35) 370 (168) 291 (132)

100014352 HMX DP16 (4.88) 505 (229) 395 (179)

22 (6.71) 685 (311) 521 (236)

100005340 HMX DP/LD12 spf DP

4 (1.22) 166 (75) 144 (65)

101210674 HMX Millennium™8 (2.44) 277 (126) 228 (103)

11 (3.35) 361 (164) 291 (132)

101343830 HNS DP16 (4.88) 491 (223) 395 (179)

22 (6.71) 666 (302) 521 (236)

100005319 RDX BH12 spf Millennium

4 (1.22) 173 (78) 144 (65)

100005326 RDX BH/LD8 (2.44) 292 (132) 228 (103)

11 (3.35) 381 (173) 291 (132)

100157006 HMX BH16 (4.88) 522 (237) 395 (179)

22 (6.71) 709 (321) 521 (236)

120038060 HMX BH/LD12 spf SH

4 (1.22) 165 (75) 144 (65)

100005311 RDX SH 8 (2.44) 275 (125) 228 (103)

101228756 RDX SH/LD 11 (3.35) 357 (162) 291 (132)

100156995 HMX SH 16 (4.88) 485 (220) 395 (179)

101233690 HMX SH/LD 22 (6.71) 657 (298) 521 (236)



Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)

101350449 RDX Excalibur 8 45°/135° 18,000(1241)

427,000(193 651) 12 spf SH

100005311 RDX SH

12 30°/150° OMNI™

18,000(1241)

427,000(193 651)

4 (1.22) 175 (79) 152 (69)

101228756 RDX SH/LD 8 (2.44) 280 (127) 230 (104)

11 (3.35) 359 (163) 288 (131)100156995 HMX SH

16 (4.88) 490 (222) 385 (175)101233690 HMX SH/LD

22 (6.71) 648 (294) 502 (228)101307494 RDX Mirage®

100005311 RDX SH

14 25.7°/128.5°

17,000(1172)

427,000(193 651)

14 spf SH4 (1.22) 177 (80) 152 (69)

101228756 RDX SH/LD8 (2.44) 286 (130) 230 (104)

11 (3.35) 368 (167) 288 (131)

100156995 HMX SH 16 (4.88) 504 (228) 386 (175)

101233690 HMX SH/LD 22 (6.71) 667 (302) 503 (228)

101268719 RDX SH 18 60°/120° 3/Plane

17,000(1172)

427,000(193 651)

18 spf SH4 (1.22) 181 (82) 152 (69)

8 (2.44) 296 (134) 229 (104)

11 (3.35) 383 (174) 288 (130)

16 (4.88) 527 (239) 385 (174)

22 (6.71) 701 (318) 501 (227)

101292616 RDX BH 21 60°/120°3/Plane

16,000(1103)

427,000(193 651)

21 spf BH4 (1.22) 185 (84) 152 (69)

8 (2.44) 304 (138) 229 (104)

11 (3.35) 393 (178) 287 (130)

16 (4.88) 540 (245) 384 (174)

22 (6.71) 717 (325) 500 (227)



Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)

100005319 RDX BH

12 OMNI™ 16,000(1103)

520,000(239 929)

12 spf 22.7 g100005326 RDX BH/LD 4 (1.22) 181 (82) 157 (71)

100157006 HMX BH 8 (2.44) 290 (132) 239 (108)

120038060 HMX BH/LD 11 (3.35) 372 (169) 300 (136)

100005324 RDX DP 16 (4.88) 505 (229) 401 (182)

100005325 RDX DP/LD 22 (6.71) 672 (305) 523 (237)

100014352 HMX DP 12 spf 28 g SH 100005340 HMX DP/LD 4 (1.22) 180 (81) 157 (71)

101210674 HMX Millennium™ 8 (2.44) 287 (130) 239 (108)

101343830 HNS DP 11 (3.35) 368 (167) 300 (136)

100005311 RDX SH 16 (4.88) 499 (226) 401 (182)

101228756 RDX SH/LD 22 (6.71) 663 (301) 523 (237)

100156995 HMX SH

101233690 HMX SH/LD

101307494 RDX Mirage®

100157007 RDX SH

14 25.7°/128.5°

16,000(1103)

520,000(239 929)

14 spf 28 g SH4 (1.22) 182 (82) 157 (71)

8 (2.44) 292 (133) 238 (108)

11 (3.35) 375 (170) 298 (135)16 (4.88) 511 (232) 399 (181)

22 (6.71) 679 (308) 520 (236)

100157011 HMX SH

14 spf 32 g SH4 (1.22) 186 (84) 157 (71)

8 (2.44) 302 (137) 238 (108)

11 (3.35) 389 (176) 298 (135)

16 (4.88) 531 (241) 399 (181)

22 (6.71) 708 (321) 520 (236)

101292616 RDX BH 21 60°/120° 3/Plane

16,000(1103)

520,000(239 929)

21 spf4 (1.22) 190 (86) 156 (71)8 (2.44) 311 (141) 236 (107)

11 (3.35) 402 (182) 296 (134)

16 (4.88) 553 (251) 395 (179)

22 (6.71) 734 (333) 515 (234)



Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)

100157007 RDX SH

14 25.7°/128.5°

17,000(1172)

512,000(232 200)

14 spf SH4 (1.22) 216 (98) 192 (87)

101307494 RDX Mirage® 8 (2.44) 344 (156) 293 (133)

11 (3.35) 442 (200) 369 (167)

101357518 RDX Excalibur 10 45°/135° 17,000(1172)

512,000(232 200)

16 (4.88) 647 (294) 496 (225)

22 (6.71) 859 (389) 648 (294)


Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)

100156993 RDX DP

12 51.4°/154.2°

15,000(1034)

672,000(304 762)

12 spf DP

4 (1.22) 272 (123) 216 (98)

100156994 HMX DP8 (2.44) 447 (203) 318 (144)

15 (4.57) 706 (320) 497 (225)

100156992 HMX BH12 spf BH

4 (1.22) 251 (114) 216 (98)

100156991 RDX BH8 (2.44) 398 (181) 318 (144)

15 (4.57) 608 (276) 497 (225)


Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)


12 45°/135° 15,000(1034)

480,000(217 687)

12 spf BH Mirage4 (1.22) 275 (125) 240 (109)

101304878 RDX Mirage8 (2.44) 431 (195) 354 (160)

16 (4.88) 733 (333) 582 (264)

101213474 RDX SH12 spf SH/LD

4 (1.22) 277 (126) 240 (109)

101212693 RDX SH/LD 8 (2.44) 435 (197) 354 (160)

101357518 RDX Excalibur 16 (4.88) 743 (337) 582 (264)

101228037 RDX Mirage

14 138° 15,000(1034)

480,000(217 687)

14 spf SH Mirage4 (1.22) 277 (124) 240 (109)

8 (2.44) 437 (198) 354 (160)

101304878 RDX Mirage SH

16 (4.88) 754 (342) 582 (264)

14 spf SH4 (1.22) 283 (128) 240 (109)

101213474 RDX SH 8 (2.44) 451 (205) 354 (160)

16 (4.88) 784 (355) 582 (264)101357518 RDX Excalibur


6 1/2-in. High-Pressure Premium VannGun® Assemblies

Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)


12 45°/135° 20,000(1379)

480,000(217 687)

12 spf BH Mirage4 (1.22) 298 (135) 268 (121)

101304878 RDX Mirage SH8 (2.44) 476 (216) 410 (186)

16 (4.88) 824 (370) 684 (310)

101213474 RDX SH12 spf SH/LD

4 (1.22) 300 (136) 268 (121)

101212693 RDX SH/LD 8 (2.44) 481 (218) 410 (186)

16 (4.88) 834 (378) 684 (310)101357518 RDX Excalibur


14 138° 20,000(1379)

480,000(217 687)

14 spf SH Mirage4 (1.22) 300 (136) 268 (121)

8 (2.44) 482 (219) 410 (186)

101304878 RDX Mirage SH

16 (4.88) 841 (382) 684 (310)

14 spf SH4 (1.22) 305 (138) 268 (121)

101213474 RDX SH 8 (2.44) 496 (225) 410 (186)

16 (4.88) 871 (395) 684 (310)101357518 RDX Excalibur


Charge Part No.




Weights

Lengthft (m)

Loadedlb (kg)

Spacerlb (kg)

100005325 RDX DP/LD

12 45°/135° 13,000(897)

802,000(363 719)

12 spf BH Mirage4 (1.22) 326 (148) 292 (132)

100005340 HMX DP/LD8 (2.44) 494 (224) 421 (191)

16 (4.88) 831 (377) 679 (308)

101228037 RDX Mirage® 12 spf SH/LD

4 (1.22) 328 (149) 292 (132)

101304878 RDX Mirage 8 (2.44) 499 (226) 421 (191)

16 (4.88) 841 (381) 679 (308)101213474 RDX SH 12 spf Millennium

4 (1.22) 356 (161) 292 (132)101212693 RDX SH/LD8 (2.44) 565 (256) 421 (191)101207997 HMX Millennium™

16 (4.88) 984 (446) 679 (308)101357518 RDX Excalibur


14 138° 13,000(897)

802,000(363,719)

14 spf SH Mirage4 (1.22) 328 (149) 291 (132)8 (2.44) 501 (227) 420 (190)

101304878 RDX Mirage SH16 (4.88) 847 (384) 677 (307)

14 spf SH

101213474 RDX SH4 (1.22) 334 (151) 291 (132)8 (2.44) 515 (234) 420 (190)

101357518 RDX Excalibur 16 (4.88) 877 (398) 677 (307)


Scalloped Gun Charge Performance Data

Size in. SPF Phasing

ExplosiveType

Part Number Charge Type

Explosive Load gm

Casing Size in.

Target Strength

psiEHD in.

Total Target

Penetrationin.

Penetration Normalized to 5,000 psi

(5% per 1,000)

Unofficial Data*

1 9/16

4 0 HMX 100157028 Millennium™ 3.4 4 1/2 5967 0.21 11.34 11.896 60 HMX 100157028 Millennium 3.4 2 7/8 6949 0.23 8.30 19B

4 0 HMX 101210199 BH 3.4 4 1/2 5000 0.30 3.20 3.20 SpecialRequest

2 6 60

HMX 101208224 Millennium 6.8 3 1/2 6470 0.26 19.20 20.61HMX 101208224 Millennium 6.8 2 7/8 6019 0.22 18.30 19B

HMX 100008017101206246

Super DPBH 6.75 3 1/2 8636 0.31 8.40 9.93

HMX 101206246 BH 6.75 2 7/8 7332 0.48 3.00 19BHMX 101206246 BH 6.75 3 1/2 6418 0.39 4.83 5.17HNS 100157018 DP 6.9 4 1/2 5960 0.23 11.80 12.37 *

2 1/2 6 60HMX 101206251 Millennium 11 3 1/2 5854 0.32 26.50 27.63HMX 101332418 Super DP 11 3 1/2 6598 0.31 20.2 19BHNS 101244923 DP 11.1 3 1/2 7128 0.26 12.60 19B

2 3/4 6 60

HMX 101233817 Millennium 15 4 1/2 6394 0.30 26.00 19BHMX 101233817 Millennium 15 4 1/2 6093 0.32 26.40 27.84HNS 101318485 Millennium 15 4 1/2 6050 0.27 21.09 *RDX 100157026 Super DP 14.7 4 1/2 5340 0.27 20.14 20.48HMX 100010399 Super DP 14.7 4 1/2 5323 0.28 21.91 22.26HNS 101251723 Super DP 15.1 4 1/2 6000 0.24 19.02 18.50 *RDX 101206793 SH 14.7 4 1/2 6109 0.67 5.50 5.80HMX 101270158 SH 14.7 4 1/2 7381 0.65 4.20 19B

2 7/8 6 60HMX 101233817 Millennium 15 4 1/2 5124 0.35 30.0 19B3

HMX 101233817 Millennium 15 4 1/2 6388 0.31 27.3 19BHNS 101388407 Millennium 18.5 4 1/2 6859 0.27 22.8 19B

3 3/8

6 60

HMX 101233819 Millennium 25 4 1/2 5754 0.45 37.50 19BHMX 101233819 Millennium 25 4 1/2 6215 0.48 40.40 42.85HNS 101265876 Millennium 25 4 1/2 6578 0.31 22.10 19BRDX 101320459 DP 22 4 1/2 7538 0.34 17.60 19BRDX 100008014 Super DP 24 4 1/2 5251 0.39 28.45 28.81RDX 101293450 Super DP/LD 24 4 1/2 5602 0.38 27.00 27.81RDX 100005321 BH 24 5 1/2 8853 0.64 4.05 **

4 G-Force® HMX 101233817 Millennium 15 4 1/2 6000 0.26 24.07 *HMX 101366678 Millennium 21 4 1/2 5671 0.39 32.57 *

12 30/150RDX 100008251 BH 14 5 1/2 7802 0.62 5.33 6.08HMX 100005312 BH 14 5 1/2 6300 0.64 5.24 5.58 *

44 90

HMX 101210636 Millennium 39 5 1/2 6365 0.38 43.40 19BHMX 101210636 Millennium 39 5 1/2 5490 0.39 44.60 45.69

6 60RDX 100005322 DP 32 7 5117 0.42 27.00HMX 100005327 DP 32 7 6155 0.46 26.80 28.35 *

4 5/8

4 G-Force

RDX 100005322 DP 32 7 5117 0.42 27.00 *HMX 101210636 Millennium 39 7 5518 0.35 43.60 *HNS 101210636 Millennium 39 7 7559 0.33 31.20 *HNS 101287306 Millennium 39 7 5/8 6349 0.29 30.20 19B

5 60HMX 101210636 Millennium 39 7 5518 0.35 43.60 19BHMX 101210636 Millennium 39 7 5502 0.37 52.00 53.31HNS 101287306 Millennium 39 7 7559 0.33 31.20 19B

6 60RDX 100005322 DP 32 7 5325 0.43 30.45 27.16HMX 100005327 DP 32 7 7098 0.46 26.80 29.61HNS 101332806 DP 32 7 5862 0.37 20.72 21.61


4 5/812 30/150

HMX 101210674 Millennium™ 22.7 7 6322 0.38 24.4 19BRDX 100005324 DP 23 7 9080 0.36 16.25 19.57RDX 100005325 DP/LD 23 7 5685 0.32 17.41 18.01HMX 100014352 DP 23 7 9080 0.37 16.09 19.37HMX 100005340 DP/LD 23 7 5685 0.30 18.37 19.00HNS 101343830 DP 21.5 7 5910 0.24 24.23 *RDX 100005319 BH 25 7 6840 0.74 6.41 7.00RDX 100005326 BH/LD 22.7 7 7346 0.65 5.51 6.16HMX 100157006 BH 25 7 5723 0.75 7.02 7.27 *RDX 100005311 SH 28 7 6982 0.93 6.30 6.92HMX 100156995 SH 28 7 5016 0.96 5.10 5.10RDX 101228756 SH/LD 28 7 5124 0.81 5.40 5.43 *HMX 101233690 SH/LD 28 7 5622 0.85 5.30 5.46

18 45/135 RDX 100156990 BH 20 7 5553 0.73 6.18 6.35

5

12

30/150 RDX 100005319 BH 25 7 6508 0.84 8.80 9.46 *45/135 RDX 101307494 Mirage® 32 7 5/8 6551 0.91 6.00 19B30/150 RDX 100005311 SH 28 7 5192 0.91 6.90 6.9730/150 HMX 100156995 SH 28 7 6487 1.00 6.00 6.45 *30/150 RDX 100005311 SH 28 7 5/8 7877 0.83 6.65 7.61

14 25.7/128 RDX 101228756 SH/LD 28 7 5/81 6437 0.66 6.00 *18 60/120 RDX 101269719 SH 28 7 5/81 5538 0.65 5.50 *21 60/120 RDX 101292616 BH 21 7 5/81 5411 0.72 5.40 19B

5 1/8

12 45/135 RDX 101307494 Mirage 32 7 5/8 5576 0.88 6.60 19B

14 25.7/128RDX 100157007 SH 32 7 5/8 5138 0.93 5.11 5.15HMX 100157011 SH 32 7 5/8 5250 0.94 5.83 5.90

21 60/120 RDX 101292616 BH 21 7 5/8 6246 0.74 5.65 5.99 *

5 3/4 14 25.7/128RDX 101307494 Mirage 32 8 5/8 6230 0.80 5.67 *RDX 100157007 SH 32 8 5/8 6498 0.75 5.87 6.31 *

6 1/2 12 or 14

45/135138

RDX 101304878 Mirage BH 47 8 5/8 7043 1.07 5.60 19BRDX 101304878 Mirage BH 47 9 5/82 5088 0.91 6.80 19B

7

12 45/135 HMX 101207997 Millennium 39 9 5/8 6397 0.42 38.70 19BHMX 101207997 Millennium 39 9 5/8 7006 0.36 43.30 47.63

12 or 14

45/135138

RDX 101228037 Mirage SH 39 9 5/8 5746 1.03 4.70 19BRDX 101304878 Mirage 47 9 5/8 6178 1.07 6.10 19BRDX 101213474 SH 56.5 9 5/8 5975 1.29 5.80 19B

12 45/135 RDX 101212693 SH/LD 56.5 9 5/8 6040 1.16 5.00 19B18 60/120 HMX 101414821 Mirage 45 9 7/84 6100 1.10 6.10 *

1 7 5/8 in. 47 lb P-110 casing2 9 5/8 in. 71 lb N-80 casing3 Gas gun, test conducted in dry casing4 62.8# C-110 casing*Indicates Un-official or QC data**API RP 4th Edition dataNotes:Charge performance data is API RP43F 5th Edition unless otherwise noted.1. Actual performance may vary due to well conditions. 2.19B data can be obtained at: http://compositelist.api.org/ProductList.ASP?Company=Jet%20Research%20Center%20(Halliburton)&Licenses=vwQPLicensesActive.license_id=3514#19B-00053.The unofficial data for 4-5/8 G-Force guns obtained from official API test shots at different phasing.

Scalloped Gun Charge Performance Data

Size in. SPF Phasing

ExplosiveType

Part Number Charge Type

Explosive Load gm

Casing Size in.

Target Strength

psiEHD in.

Total Target

Penetrationin.

Penetration Normalized to 5,000 psi

(5% per 1,000)

Unofficial Data*



Gun Washover/Fishing Specifications

Gun Size in.

Gun ODin.*

(Gun OD after shooting)

Maximum Shot(Density) per foot

SPF

Minimum Casing Size

(for washing over w/o

milling guns)

1.5631.745 4

4 in.1.76 6

22.166 4

4 in.2.203 6

2.5TBD* 4

4.5 in. 13.5 #/ft2.67 6

2.75

2.97 4

4.5 in. 9.5 #/ft2.79 5

3.09 6

3.125 3.25 9 5 in. 15 #/ft

3.375

3.68 4

5.5 in. 23 #/ft3.68 6

3.53 12

4 4.26 6 6 5/8 in. 35 #/ft

4.625

4.87 5

7 in. 35 #/ft

4.88 6

4.86 8

4.87 11

4.96 12

4.79 14

5

5.2 12

7 in. 26 #/ft/**5.3 14

5.23 18

5.125

5.41 6

7 5/8 in. 39 #/ft5.21 12

5.38 14

5.36 21

6 6.79 12 9 5/8 in.

6.5 6.76 14 9 5/8 in. 71.8 #/ft

77.14 12

9 5/8 in. 58.4 #/ft7.15 14

*Worst Case-Atmospheric pressure, submerged in water.**It is possible to washover 5 in. guns in 7 in. 29-lb casing, but washover pipe to be used is not a common size and is difficult to find.


Gun Swell Information

Gun Charge Test Results

OD SPFShot Phase

degCharge Part No. Type

Explosive Weightgm

Tested InAir/Water

Maximum Swellin.

1 9/16 660 100157028

Millennium™ 3.4 water1.760

0 100157028 1.705

2

4 0 100008017SDP

6.8

air 2.246

6

60 100008017

water

2.221

0 101208224Millennium

2.177

60 101208224 2.225

2 1/2 6 60 101206251 DP 11 water 2.680

2 3/4

4 22 LS 100158220 DP LD

13

water

2.781

5 180100158220 13 2.810

100157026 SDP 14.7 2.971

660

100005329 DP

12.5 2.853

100005329 12.5 air 2.898

100158220 DP LD 13

water

2.893

101206793 BH 14.7 2.850

100010399 SDP 14.7 2.954

101233817Millennium

15 2.892

60 LS 101233817 15 2.915

2 7/8 6 60 101233817 Millennium 15 water 3.047

2 7/8 HW 6 60 101233817 Millennium 15 air 3.044

3 3/8

G-Force® 180 101233817 Millennium 15 water 3.42

4

60100005322

DP

32 air 3.676

100005327 32

water

3.592

90 100005327 32 3.555

180 100008249 SDP 25 3.546

6

60

100005333 DP 22 air 3.610

100008249 SDP 25

water

3.600

101207640 SDP LD 24 3.615

60 LS 100008249 SDP 25 3.600

60101233819 Millennium 25 3.645

101309223 Dominator® 25 3.695

8 180 100008251

BH

14 3.458

1230/150

100008251 14 3.520

12 100005312 14 3.568

44 90 101210636 Millennium 39 water 4.260

7 150 101228756 SH LD 28 water 4.280


Gun Swell Information

Gun Charge Test Results

OD SPFShot Phase

degCharge Part No. Type

Explosive Weightgm

Tested InAir/Water

Maximum Swellin.

4 5/8

G-Force® 180 100005327 DP 32 water 4.696

560 101210636 Millennium™ 39 air 4.944

45/135 101321963 SH 56.5 water 4.904

6 60100005327

DP32 air 4.876

100005327 32 water 4.806

8 180

100005326DP LD

23 air 4.860

100005326 23

water

4.780

100005311 SH 28 4.770

11 140/160 100005324DP

22.7 4.868

12 30/150

100014352 23 4.834

100005340 DP LD 22.7 4.925

100005326 BH LD 22.7 4.840

100005311 SH

28

4.813

101228756 SH LD 4.895

14 25.7/128.5 100005311 SH 4.790

18 45/135 100156990 BH 20 4.730

5

12 30/150 100005311SH

28water

5.196

14 25.7/128.5100005311 5.207

101228756 SH LD 5.304

1860/120

101269719 SH 5.229

21 101292616 BH 21 5.198

5 1/8

6 45/135 101240223 SH 56.5

water

5.413

12 30/150 100005326 BH LD 22.7 5.210

14 25.7/128.5 100157007 SH 32 5.332

21 60/120 101292616 BH 20 5.268

5 3/4 14 25.7/128.5 101272769 SH LD 34 water 5.945

6 1/214 138 101304878 Mirage® BH 47

water6.685

12 45/135 101212693 SH LD 56.5 6.715

6 1/2 HP 12 45/135 101212693 SH LD 56.5 water 6.762

712 45/135 101210063 SH LD

56.5 water7.125

14 138 101213474 SH 7.143

The above chart was taken from actual tests conducted by Halliburton Technology on RDX and HMX charges. It can be used as a general guideline for all explosives. If you have questions regarding these systems, or systems that are not listed, please contact your local Halliburton representative.All tests were conducted at ambient temperature and pressure.


VannGun® Pressure Ratings

Halliburton VannGun® assemblies have remained an industry-leading product because of Halliburton’s commitment to high quality construction. Halliburton uses only the best materials and conducts rigorous tests to ensure a reliable VannGun assembly.

VannGun assemblies are rated to a specific collapse and tensile strength. Each system is qualified at 450°F (232°C) and meets all the requirements of API RP 19B Section 3: Evaluation of Well Perforators. All VannGun assemblies are made of a high quality seamless tubular that must meet strict metallurgical and mechanical property standards.

In addition to these requirements, during testing, each test gun is cut with a minimum scallop thickness to ensure the scallop is not a failure point. Using these criteria also reduces any additional strength a thicker scallop may bring to the area around the scallop.

Once a VannGun collapse test has been conducted and documented, the information is reviewed. If a VannGun assembly is collapsed during testing, the initial gun rating is reduced to the last pressure at which it survived for one hour. If no failure occurred, the VannGun initial rating will be the last pressure at which the gun survived for one hour before the testing was terminated.

After the initial rating has been determined, the rating is reduced to reflect a gun cut to minimum material conditions. This ensures that even if a VannGun assembly is manufactured to the worst allowable tolerances, it will still survive the pressure rating. After the adjustment is made for minimum material conditions, the gun rating is lowered again so there is a minimum safety factor of 5% as required by API RP 19B Section 3: Evaluation of Well Perforators. These calculations may be found in the section marked “Collapse Rating Calculations” for each VannGun assembly tested.

In some instances, the maximum collapse pressure rating of VannGun assemblies may be higher than tested since the pressure chamber used to qualify most VannGun assemblies do not exceed a pressure of 30,000 psi (2068 bar). A pressure chamber that allowed higher pressures in some cases would allow higher ratings for VannGun assemblies.

The raw material and test criteria under which VannGun assemblies must be tested help ensure every VannGun run will survive the required collapse pressure rating.

Thermal Decomposition of Explosives

Explosives are energetic materials with decomposition rates that are exponential functions of temperature. At room temperature, where the decomposition rate is extremely small, the effective shelf life of an explosive can be one million years. However, the same material will react within microseconds at 825oC. Other decomposition rates and corresponding lifetimes exist between these two extremes. The decomposition of explosives is a process that generates heat and releases gaseous by-products. This decomposition is called “thermal outgassing” and if the heat generated by decomposition can be balanced by heat dissipation to the surroundings, then the explosive quietly decomposes until none remains. If, however, the heat generated by decomposition is not removed quickly enough, then it is possible for the process to become unstable and the reaction to accelerate uncontrollably until an explosion occurs (sometimes called “thermal runaway”). The process can be stated in simple terms.

The first term on the right-hand side of the equation is an exponential function of temperatures. The second term is linear with respect to temperature. Thus, it becomes apparent that as the temperature increases, the heat generated by decomposition quickly begins to dominate and can result in a variety of outcomes, including catastrophic thermal explosion. To aggravate the process further, it is also possible that the gaseous by-products generated by decomposition can serve as catalysts to the reaction, thus increasing the rate even more.

Rate of temperature rise in the explosive

=

Rate of heat generation due to decomposition

-

Rate of heat loss to the surroundings due to conduction


The outcomes of thermal decomposition are somewhat distinct and can be divided into the following categories:

• Full detonation—a supersonic reaction consuming all explosive material. Fragments are formed from metallic charge cases, and jets are produced from lined cavity devices.

• Partial detonation— some of the energetic material is consumed by detonation, but other explosive material may be thrown burning or unreacted. The reaction along the length of the explosive train may cut off.

• Explosion (strong deflagration)— a subsonic but rapid burning of the explosive material leading to violent rupture of confining cases and pressure vessels.

• Deflagration—a slightly less rapid reaction than an explosion but still sufficiently strong enough to rupture cases and pressure vessels into large, relatively slow-moving pieces.

• Burning (weak deflagration)—a consumption of energetic material by flame. No significant breakup of cases or metallic components occur. The “shell” of detonating cord may remain intact.

• Exudation (extrusion)—the energetic material extrudes, or flows out of its confining structure. Exudation may result in the energetic material coming into contact with other materials not chemically compatible with energetics, which may stimulate more violent reactions.

• Performance degradation— no violent reactions have occurred, but the explosive has thermally degraded to the point it compromises performance and/or reliability.

• Quiet decomposition— the explosive has decomposed at a rate corresponding to its thermal history, but the amount of decomposition is so slight it does not compromise performance or reliability.

In order to provide guidelines for quiet decomposition versus violent events, time-temperature curves have been generated for various explosives. As long as conditions remain below the time-temperature curve for a given explosive, it will function properly.

If conditions go above the curve, quiet decomposition may or may not take place, which means it is entirely possible that a violent event can occur. Thus, procedures are in place to stay below the curves. It is also important to recognize that no safety factor has been built into these curves, and this must be accounted for when planning any downhole job requiring the use of energetic materials. Always consider the accuracy of the bottomhole temperature and how long the explosives will remain at that temperature under worst case conditions. Adjust accordingly. Past experience related to exposure time has shown that a minimum safety factor of 50% should be applied when choosing the explosive type. For example, if the estimated time on bottom is 60 hours, then add 30 hours for a total of 90 hours when selecting an explosive from the time-temperature chart.

The curve is applicable only for hollow carrier guns where the explosive is exposed solely to the effects of temperature. In the case of capsule guns, where detonation cord is exposed to both temperature and pressure, the time-temperature relationship is different. Also, the dotted-line portions of the curves are extrapolations of what the time-temperature relationships would be for longer exposure times. For any jobs that fall in these extrapolated ranges of time, it is mandatory that an explosive systems test be conducted at Halliburton Technology.

For more information on the subject of thermal decomposition, please contact your local Halliburton representative.


Time Vs. Temperature Chart

Operational Limits for Hollow Carrier Gun Systems

650

600

550

500

450

400

350

300

250

200

150

1 10 100 1000

PYX

HNS

HMX

RDX

TIME (Hours)

CONTACT HALLIBURTON TECHNOLOGY FOR RECOMMENDATIONS AND POSSIBLE NEEDFOR SYSTEMS TESTING.

Te

mp

era

ture

°F

343

316

288

260

232

204

177

149

121

93

661 10 100 1000

PYX

HNS

HMX

RDX

TIME (Hours)

Te

mp

era

ture

°C

CONTACT FOR RECOMMENDATIONS AND POSSIBLE NEEDHALLIBURTON TECHNOLOGYFOR SYSTEMS TESTING.

Notes:1. This chart is valid for the explosive train inside hollow carrier guns only: Non-electric boosters,

detonating cord, and shaped charges.2. It is not valid for TCP firing systems, electric detonators, or capsule guns.3. Contact your local Halliburton representative for information regarding these other components.

Firing H

eads

Firing Heads

Time Vs. Temperature Charts (page 4)These charts display time vs. temperature for the PYX initiator, time-delay firer, and high temperature initiator.

Detonation Interruption Device (page 5)The detonation interruption device provides added safety for the VannSystem® service by helping to prevent firing at surface conditions. The detonation device contains eutectic metal that has a very low melting point. When the metal is in a solid state, the firing head could detonate, but the explosive train will not transmit through the interrupt device to the guns.

Mechanical Firing Head (page 6)The extended mechanical firing head (MFH) is a special application tool that should only be used when well conditions preclude use of an alternate firing device.

Model II-D and III-D Mechanical Firing Head (pages 7-8)The model II-D and III-D mechanical firing heads are pressure-assisted mechanical firing heads. The detonating bar strikes the firing pin, releasing the firing piston. Hydrostatic pressure then forces the firing piston into the initiator.

Pressure-Actuated Firing Head (page 9)

The pressure-actuated firing head can run with small OD tubing or coiled tubing to detonate small OD perforating guns and is detonated by applied pressure.

Model K Firing Head (page 10)The model K firing heads were developed for conditions that are unfavorable for dropping a detonating bar in a horizontal well. The model K firing head is a pressure-sensitive tool designed to hydraulically detonate at a prescribed pressure. These firing heads use tubing pressure applied to a piston-type firing pin.

Model KV-II Firing Head (page 11) Combining a firing head with a vent assembly, the model KV-II firing head makes firing of the guns and opening of the vent one operation instead of two. This tool helps allow the operator more accurate control of when the vent opens in relation to when the guns fire.

Time-Delay Firer (page 12)

The time-delay firer (TDF) allows under- or overbalanced perforating through the use of a pressure-actuated firing head with a time delay fuse. With the delay fuse, there is time for adjusting the actuating pressure in the tubing to achieve the desired pressure before firing the guns.

Multiaction-Delay Firing Head (page 13)The multiaction-delay firing head is a pressure-actuated redundant firing system that can be run with any one of several other firing heads.

Annulus Pressure Firer-Control Line (page 14)The annulus pressure firer-control line (APF-C) was developed as a dual-firing system that allows the perforating guns to be detonated by annular pressure, a drop bar, or tubing pressure. The APF-C system consists of a pressure transfer reservoir, a sleeve through the packer mandrel, an adapter below the packer, and a control line to transmit pressure from the annulus above the packer to the APF-C firing head assembly on top of the guns. Any of the mechanical or pressure-firing heads can be attached to the top of the APF-C firing head.

Annulus Pressure Transfer Reservoir (page 15)The annulus pressure transfer reservoir (APTR) is an integral component of the APF-C. It is the mechanism that transmits pressure from above the packer to a differential pressure or pressure-actuated firing head on top of the perforating assembly.

Slimhole Annulus Pressure Firer—Internal Control (page 16)The slimhole annulus pressure transfer reservoir (APTR) system assembles in a similar manner to the 7-in. and 9 5/8-in. APTR systems. Only two design changes have been implemented in the new 5-in. APTR system. First, a series of concentric tubes below the packer replaces the control line from larger APTR systems. Second, a single tube mandrel runs through the packer, replacing the series of threaded tube mandrels from the larger APTR systems.

Firing Heads 5-1

Differential Firing Head (page 17)

The differential firing head was designed to allow underbalanced perforating with a differential pressure-actuated firing system. The firing head works by requiring the internal pressure to be greater than the external pressure. This condition can be created when pressure is applied to the ID or when the OD pressure is reduced. The pressure required to actuate the firing head may be lower than that used for other pressure-operated firing heads because it is operated by differential pressure.

Hydraulic Actuator Firing Head and Swivel-Type Hydraulic Actuator Firing Head (page 18)

The hydraulic actuator firing head (HAF) is a pressure-balanced tool that automatically fills the tubing string while it is running in the well. A stainless steel ball is dropped from the surface or circulated into position. Pressure applied to the tubing string actuates the HAF. A smaller swivel-type hydraulic actuator firing head incorporates a swivel into the firing head assembly, which allows the lower portion of the firing head and the attached explosive assembly to rotate independently from the tubing string.

Mechanical Metering Hydraulic-Delay Firing Head (page 19)

The mechanical metering hydraulic-delay firing head provides a retrievable firing system with an adjustable delay for situations where longer delay times are needed. Delay time can be adjusted and is affected by temperature, tool weight above the piston, the number of jets used, and the amount of fluid in the tool.

Slickline-Retrievable Mechanical Firing Head (page 20)

The slickline-retrievable mechanical firing head is designed to give customers flexibility in completing a well. It can be run attached to the guns, separately from the guns, or using an auto-release firing mechanism. The firing head latches onto the guns and provides a positive indication that it is attached. The system can be run with a mechanically operated head or a pressure-operated head. It is designed so 80% of the parts are used in all three applications allowing for more flexibility with less inventory.

Slickline-Retrievable Time-Delay Firer Firing Head (page 22)

The slickline-retrievable time-delay firer (TDF) firing head combines two assemblies—the slickline-retrievable firing head and a 1 11/16 in. TDF firing head. It is a pressure-actuated firing head with built-in pyrotechnic time delay.

Extended Delay Fuses (page 23)

Delay fuses are explosive devices with a slow burning fuse. Extended and modular delay fuses add time between the actuation of the firing head and the actual detonation of the guns. Each delay fuse lasts for six minutes at 70°F.

Modular Mechanical Firing Head (page 24)

Mechanical firing head is designed to be a retrievable firing system utilizing a standard mechanical firing head with a specialized drop bar for detonation. This system will allow the operator the flexibility to run the gun assemblies independently of the firing system. Once the guns are in place, the firing head is set on the top module and released. The perforation assembly is detonated by use of a special fluted bar dropped from surface.

HalSonics® Firing Head (page 26)

The HalSonics® firing head system is designed to actuate tubing conveyed perforating guns and may be conveyed by tubing, slickline, or electric line. This system can overcome obstacles in jobs where bar-drop or pressure actuated firing heads are not technically feasible or economically practical to detonate the downhole perforating assembly. In addition, this system can be utilized when extensive well fluid manipulations are required or where multiple pressure cycles are performed prior to perforating. The HalSonics firing head is also ideal for applications where extremely long delay times are required with traditional delay type firing systems.

5-2 Firing Heads

Side-Pocket Mandrel Firing Head (page 28)

The side-pocket mandrel firing head is useful in well conditions when the use of a pressure-actuated firing head run with a Y-block is not possible. Side-pocket systems are used on single-string, multi-zone completions as well as standard dual completions. A model III-D mechanical firing head is attached to the short string side of the mandrel and the firing head is detonated with a kickover tool run on slickline.

Annulus Pressure Crossover Assembly (page 29)

The annulus pressure crossover assembly allows the use of annulus pressure to actuate any one of several firing heads. The assembly is compatible with retrievable packers of all types and sizes.

EZ Cycle™ Multi-Pressure Cycle Firing Head (page 30)

The EZ Cycle™ firing head is a pressure-operated tool that can be cycled several times prior to firing the perforating guns. Several pressure operations can also be performed on the well including tubing testing, packer setting and packer testing prior to firing the perforating guns.

Firing Heads 5-3

300

500

1 10 100 1000

350

400

450 PYX450

437

PYX initiator -- 450 deg F @ 100 hrs 437 deg F @ 200 hrs

HTI -- 437 deg F @ 200 hrs 395 deg F @ 500 hrs

TDF -- 425 deg F @ 200 hrs 375 deg F @ 500 hrs

HTI

425TDF

TDF HTI PYX

375

3951. Temps noted on the graph are actual test points.

3. If you have an application for any of these items that exceeds either the time or temps ofthe actual test data as shown on this graph, we would recommend a qualification test bedone.

THESE RATINGS ARE FOR SPECIFIC SCIENTIFIC MANUFACTURED PRODUCTS ONLY

2. The dashed lines are extrapolations out to 1000 hrs.

Tem

pera

ture

(deg

F)

PYX Initiator TDF & HTI – Time Vs. Temperature Chart

Time (hr)

150

250

1 10 100 1000

200

PYX 232

225

PYX initiator -- 232 deg C @ 100 hrs 225 deg C @ 200 hrs

HTI -- 225 deg C @ 200 hrs 202 deg C @ 500 hrs

TDF -- 218 deg C @ 200 hrs 191 deg C @ 500 hrs

218TDF

TDF HTI PYX

191

HTI

202

1. Temps noted on the graph are actual test points.

2. The dashed lines are extrapolations out to 1000 hrs.

3. If you have an application for any of these items that exceeds either the time or tempsof the actual test data as shown on this graph we would recommend a qualification testbe done.

THESE RATINGS ARE FOR SPECIFIC SCIENTIFIC MANUFACTURED PRODUCTS ONLY.

Time (hr)

Tem

pera

ture

(deg

C)

PYX Initiator, TDF & HTI – Time Vs. Temperature Chart (Metric)

5-4 Firing Heads

Detonation Interruption Device

The detonation interruption device (DID) provides added safety for the VannSystem® service by helping to prevent firing at surface conditions. This device contains a eutectic metal that has a very low melting point. When the metal is in a solid state, the firing head could detonate, but the explosive train will not transmit through the interrupt device to the guns.

Features and Benefits

• Compatible with other firing heads

• Disables transmission of explosive train at the surface

• Used with redundant firing heads

Operation

The eutectic metal will remain solid as the assembly lowers into the hole (assuming the tool temperature is below 117°F). When exposed to the bottomhole temperature (minimum 135°F for operational purposes), the metal becomes liquid, allowing the transfer of the explosive train from the firing head to the gun.

To help prevent accidental gun detonation when lowering or retrieving unfired guns, the metal returns to a solid state upon reaching a cooler surface temperature.

Note: The eutectic material utilized actually melts at 117°F. At 117°F or above, the DID assembly will not prevent detonation. For safe operation, it should be assumed that detonation transfer will occur if the tool is at or above 110°F.

Detonation Interruption Device

HA

L1

05

19

Detonation Interruption Device (DID) Specifications

SAP No.

Thread Size and Typein. (mm)

Maximum ODin. (mm)

Makeup Lengthft (m)

Maximum Operating Pressurepsi (bars)

Minimum Required Temperature Rating

°F (°C)Tensile Strength

lb (kg)

100155745 2 (50.8) 6Acme 2G

2.50(63.5)

1.58(0.48) N/A 135

(57)121,000(54 885)

101204860 2 3/8 (60.33) 6P Acme Box × Pin

2.75 (69.85)

3.70 (1.13)

20,000 (1380)

135 (57)

140,000 (63 400)

100155746 2 7/8 (73.03) 6P Acme Box × Pin

3.375 (85.73)

3.04 (0.93)

25,000 (1725)

135 (57)

246,000 (111 500)

Maximum temperature is determined by explosives.These ratings are guidelines only. For more information, consult your local Halliburton representative.

Firing Heads 5-5

Mechanical Firing Head

The extended mechanical firing head (MFH) is a special application tool. It should be used only when well conditions preclude the use of an alternate firing device. Whenever it is used on a job, the MFH must be used according to Halliburton standard operating procedures.

Operation

HA

L1

53

76

HA

L1

53

58

Mechanical Firing Head (MFH)

Firing Head Sub-Assembly

The operation of the MFH depends on the amount of force delivered to the firing pin by the detonating bar. This firing pin must be hit with enough force to shear the spiral pin, which holds the firing pin in place, and to detonate the initiator. The firing pin is driven into a percussion detonator, which fires the guns.

The detonation interruption device (DID) and a minimum of 10 ft of safety spacer must always be used with the MFH.

Mechanical Firing Head (MFH) Specifications

SAP No.


Maximum ODin. (mm)

Make-up Length(w/tubing sub)

ft (m)


Minimum ID (No-Go)in. (mm)

Tensile Strength (FH Body)

lb (kg)

100155741 1 7/16 (36.51) 8 UN 2 B Box × 1.90 (48.26) NU 10 Rd Pin

2.0 (50.8)

1.48(.45)

20,000(1380)

1.53 (38.86)

60,000(27 200)

100005223 1.90 (48.26) NU 10 Rd Pin × 2 3/8 (60.33) 6P Acme Box

2.75 (69.85)

4.92(1.50)

20,000(1380)

1.56 (39.62)

140,000 (63 400)

100005228 2 3/8 (60.33) EUE 8 Rd Pin × 2 7/8 (73.03) 6P Acme Box

3.375 (85.73)

4.92 (1.50)

20,000(1380)

1.56 (39.62)

238,000(107 900)

Burst and collapse pressures are determined by handling sub.Temperature rating is determined by explosives.These ratings are guidelines only. For more information, consult your local Halliburton representative.

5-6 Firing Heads

Model II-D Mechanical Firing Head

The model II-D mechanical firing head is a pressure-assisted mechanical firing head. The detonating bar strikes the firing pin, releasing the firing piston. Hydrostatic pressure then forces the firing piston into the initiator.


• Cannot be detonated accidentally at surface

• Ideal for use in mud environments where spudding may be necessary

• Used in deviated wells

Operation

The model II-D firing head requires a minimum of 1,500 psi hydrostatic pressure in the tubing to actuate the firing head properly.

Adding more pressure to the tubing after the detonating bar has struck the firing pin will not actuate the firing head.

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L1

53

77

HA

L15378

Model II-D Mechanical Firing Head

Model II-D Mechanical Firing Head Assembly

Model II-D Mechanical Firing Head Specifications

SAP No.Thread Size and Type

in. (mm)

Maximum OD

in. (mm)

Minimum ID (No-Go) in. (mm)

Makeup Length(w/tubing sub)

ft (m)

Maximum Operating Pressure psi (bars)

Minimum Operating Pressure psi (bars)

Tensile Strength

(FH body)lb (kg)

1000141561.90 (48.26) EUE 10 Rd

Pin × 2 3/8 (60.33) 6P Acme Box

2.75 (69.85)

1.56 (39.62)

4.92 (1.50)

20,000 (1380)

1,500 (103)

140,000 (63 400)

100005227 2 3/8 (60.33) EUE 8 Rd Pin × 2 7/8 (73.03) 6P Acme

3.375 (85.73)

1.56 (39.62)

4.92 (1.50)

20,000 (1380)

1,500 (103)

238,000 (107 900)


Firing Heads 5-7

Model III-D Mechanical Firing Head

The model III-D mechanical firing head is a pressure-assisted mechanical firing head. The detonating bar strikes the firing pin, releasing the firing piston. Hydrostatic pressure then forces the firing piston into the initiator.

The model III-D firing head requires a minimal amount of hydrostatic pressure to actuate the firing head.


• Cannot be detonated accidentally at surface

• Requires minimal hydrostatic pressure to actuate the firing head

• Ideal for use in mud environments where spudding may be necessary

• Used in deviated wells

Operation

The model III-D firing head requires a minimum of 250 psi hydrostatic pressure in the tubing to actuate the firing head properly. This minimal actuating pressure is ideal for applications that require maximum differential pressures.

If a detonating bar is dropped on the model III-D firing head with less than 250 psi hydrostatic pressure in the tubing, and the head does not fire, increasing the hydrostatic pressure in the tubing may cause it to fire.

HA

L1

53

79

HA

L1

53

80

Model III-D Mechanical Firing Head

Model III-D Mechanical Firing Head Assembly

Model III-D Mechanical Firing Head Specifications


in. (mm)

Maximum OD

in. (mm)

Minimum ID (No-Go) in. (mm)

Makeup Length

(w/tubing sub) ft (m)



Tensile Strength (FH Body)

lb (kg)

100155742 1.90 (48.26) EUE 10 Rd Pin × 2 3/8 (60.33) 6P Acme Box

2.75 (69.85)

1.56(39.62)

4.92 (1.50)

8,000 (550)

250 (17)

140,000 (63 400)


3.375 (85.73)

1.56 (39.62)

4.92 (1.50)

8,000 (550)

250 (17)

238,000 (107 900)


5-8 Firing Heads

Pressure-Actuated Firing Head

The 1 11/16-in. pressure-actuated firing head (PAF) can run with small-OD tubing or coiled tubing to detonate small-OD perforating guns. The PAF is detonated by applied pressure.


• Can be run on the top and bottom of the gun assembly

• Initiates a bridge-plug setting tool

• Initiates tubing cutters

• Detonates tubing punch charges for squeeze or circulating jobs

• Can be run to remain closed after detonation

• Can be modified to be run as a slickline-retrievable firing head and a time-delay firing head (TDF)

Operation

The 1 11/16-in. PAF consists of an upper housing with circulating ports, a firing piston that is shear-pinned in place across the circulating ports, and an initiator contained in a lower housing.

Pressure applied to the tubing string shears the shear set, which forces the firing piston into the initiator to detonate the explosive component attached to the PAF. The downward movement of the firing piston opens the circulating ports.

Pressure-Actuated

Firing Head (PAF)

HA

L10561

Pressure-Actuated Firing Head (PAF) Specifications

SAP No.


Maximum OD

in. (mm)

No. and ID of Ports in. (mm)

Flow Area of Ports

in.2 (cm2)

Makeup Lengthft (m)



Tensile Strength lb (kg)

Collapse Pressure psi (bars)

1000052241.315 (33.40) NU-10 Rd

Pin × 17/16 (36.51) 8 UN-2 B Box

1.688 (42.88)

2 @ 0.75 (19.05)

0.88 (5.68)

0.73 (0.22)

17,000 (1170)

2,200 (150)

65,000(29 400)

27,000 (1860)

Temperature rating is determined by explosives.These ratings are guidelines only. For more information, consult your local Halliburton representative.

Firing Heads 5-9

Model K Firing Head

The model K firing head was developed for conditions that are unfavorable for dropping a detonating bar in a horizontal well. The model K firing head is a pressure-sensitive tool designed to hydraulically detonate at a prescribed pressure. These firing heads use tubing pressure applied to a piston-type firing pin.


• Allows the operator to determine the exact time of firing the guns since the firing heads require a predetermined pressure before the guns can fire

• Works with full-opening or non-full-opening downhole tools

• Ideal for balanced or overbalanced perforating

• Can be used for dual completions, drillstem testing, or production perforating

• Well-suited for highly deviated well completions

• Can be run on the top or bottom of the perforating assembly

• Can be easily redressed

Operation

The model K firing head is designed to provide a reliable and cost-effective method for firing guns using hydrostatic pressure. Each firing head contains a firing piston that is shear-pinned in place above an initiator. The number of shear pins used varies for each well situation.

When enough hydrostatic pressure is applied to the piston, the shear pins shear, thereby allowing the firing pin on the lower end of the piston to be driven into the initiator. This action detonates the guns. These firing heads do not have a built-in delay.

Model K Firing Head

HA

L1

53

81

Model K Firing Head Specifications


in. (mm)Maximum OD

in. (mm)

Makeup Length ft (m)





100014211 2 7/8 (73.03) EUE 8 Rd Box × 2 7/8 (73.03) 6P Acme Box

3.375(85.73)

1.25(0.38)

13,000(895)

4,000(275)

220,000(99 700)

30,000 (2070)

993.01082* 2 7/8 (60.33) 6P Acme Box × 4 1/2 (114.3) IF Box × Pin

6.12(155.45)

1.13(0.34)

13,000(895)

4,000(275)

1,000,000 (453 500)

30,000 (2070)

*Legacy number

Model K-II Firing Head Specifications


in. (mm)

Maximum OD

in. (mm)






100005190 1.90 (48.26) EUE 10 Rd Pin × 2 3/8 (60.33) 6P Acme Box

2.75 (69.85)

1.24 (0.38)

19,500 (1345)

4,000 (275)

187,000 (84 800)

25,000 (1725)


3.375 (85.73)

1.64 (0.50)

19,500 (1345)

4,000 (275)

220,000 (99 700)

30,000 (2070)


5-10 Firing Heads

Model KV-II Firing Head

The model KV-II firing head makes the firing of the guns and the opening of the vent one operation rather than two. This tool allows the operator more accurate control of when the vent opens in relation to when the guns fire.


• Useful in wells with open perforations where it is not possible to pressure up on the wellbore to actuate a firing head

• Useful in perforating and stimulation jobs where the tubing pressure exceeds the limitations of the casing

• Useful because the firing head and vent operate at one pressure

• Ideal for deviated wells

• Piston mechanically locked after firing

Operation

In many tubing conveyed perforating applications, it is either desirable or necessary to keep the tubing closed until the guns have been detonated. In the past, the tubing was kept closed by a firing head with some type of vent assembly. Coordination between the two tools was sometimes hard to achieve, and the vent often opened either too soon or too late. The model KV-II firing head combines a firing head and a vent assembly.

In the model KV-II firing head, a piston is sheared to cause the guns to detonate and the ports to open and equalize (or vent) pressure. This venting feature allows operators to run the tubing in the hole dry if needed. In the standard KV-II firing head, the ports in the tool open the instant the firing head is actuated and the guns detonate. To delay the gun detonation, one or more delay devices may be added to the assembly.

Model KV-II

Firing Head

HAL

1545

9

Model KV-II Firing Head Specifications

SAP No.

Thread Sizeand Typein. (mm)

Maximum OD

in. (mm)Flow Area in.2 (cm2)

Minimum Makeup Lengthft (m)



Maximum Differential Pressure psi (bars)


100014153 2 3/8 (60.33) EUE 8 Rd Pin × 2 3/8 6P Acme Box

2.75 (69.85)

2.79 (18.0)

1.33 (0.41)

25,000 (1725)

3,000 (206)

15,000 (1035)

145,000(65 700)

100014155 2 7/8 (72.88) EUE 8 Rd Pin × 2 7/8 6P Acme Box

3.375 (85.73)

3.14 (20.27)

1.43 (0.44)

25,000 (1725)

4,000 (275)

15,000 (1035)

235,000(106 600)


Firing Heads 5-11

Time-Delay Firer

The time-delay firer (TDF) allows under- or overbalanced perforating through the use of a pressure-actuated firing head with a time-delay fuse. The delay fuse allows 4 to 6 minutes for adjusting the actuating pressure in the tubing to achieve the desired pressure before firing the guns.


• Allows independent perforating of selected zones

• Allows maximum use of under- or overbalanced pressure

• Can be run in heavy mud systems

• Can be used with full-opening or non-full-opening tools

• Reduces cost by allowing the running of multiple guns without gun spacers

• Ideal for production completions, drillstem testing, and dual completions

• Recommended for running on the top and bottom of gun assemblies

• Allows additional time-delay elements as needed for increasing delay time

Operation

The TDF is run with a predetermined number of shear pins for specific well conditions. The tubing is pressured to the maximum actuating pressure slowly. The maximum pressure shears the pins in the shear set and forces the firing piston into the primer. The primer ignites the pyrotechnic delay fuse. The delay fuse burns for a predetermined time (between 4 and 6 minutes) depending on the bottomhole temperature and detonates the perforating assembly.

Time-Delay

Firer (TDF)

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L1

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82

Time-Delay Firer (TDF) Specifications

SAP No.


Maximum OD

in. (mm)




Temperature Rating °F (°C)



100014157 1 7/16 (36.51) 8 UN-2 B Box × 1.315 (33.4) NU-10 Rd Pin

1.688 (42.88)

2.16 (0.65)

17,000 (1170)

2,200 (150)

425 (218) for 200 hours

56,000 (25 400)

20,000 (1380)

100005231 1.90 (48.26) EUE 10 Rd Pin × 2 (50.8) 6P Acme Box

2.50 (63.5)

1.69 (0.52)

24,000 (1655)

4,000 (275)

415 (213) for 100 hours

120,000 (54 432)

30,000 (2070)


3.375 (85.73)

1.81(0.55)

13,000 (895)

4,000 (275)

425 (218) for 200 hours

220,000 (99 700)

30,000 (2070)


5-12 Firing Heads

Multiaction-Delay Firing Head

The multiaction-delay firing head is a pressure-actuated redundant firing system that can be run with any one of several other firing heads.


• Allows the use of a redundant firing head without having a firing head on the bottom of the gun string

• Allows multiple redundancy when a multiaction firing head is placed on both the top and bottom of the gun string

• Allows operators to postpone the decision of whether to use the bar drop or pressure side of the firing head as the primary firing mechanism

• Allows use of additional delay elements

Operation

One side of the multiaction firing head will always be pressure-actuated. The other side of the firing head may be a bar drop-type head or another pressure-actuated firing head. Either side of the firing head may be used as the primary or backup firing system.

Multiaction-Delay

Firing Head

HA

L1

05

11

Multiaction-Delay Firing Head Specifications

SAP No.

Thread Size and Type

in. (mm)Maximum OD

in. (mm)

Makeup Lengthft (m)





100155753 2 3/8 (60.33) 6P Acme Box × Pin

3.10(78.74)

3.41(1.04)

18,000 (1240)

4,000 (275)

170,000 (77 100)

22,000 (1515)

100155750 2 7/8 (73.03) 6P Acme Box × Pin

3.375(85.73)

3.41(1.04)

25,000 (1725)

4,000 (275)

201,000 (91 100)

29,000 (2000)


Firing Heads 5-13

Annulus Pressure Firer-Control Line

The annulus pressure firer-control line (APF-C) was developed as a dual-firing system that allows the perforating guns to be detonated by annular pressure, a drop bar, or tubing pressure. The APF-C system consists of a pressure transfer reservoir, a sleeve through the packer mandrel, an adapter below the packer, and a control line to transmit pressure from the annulus above the packer to the APF-C firing head assembly on top of the guns. Any of the mechanical or pressure-firing heads can be attached to the top of the APF-C firing head.


• Can be used with non-full-opening test tools and partially filled tubing strings

• Can be used for drillstem testing or shoot-and-pull for gravel packs

• Can be used wherever a pressure-actuated tool is desirable

• Ideal for deviated wells

• Provides a system of two firing heads on top of the guns

• Can be run with a mechanical or pressure-actuated firing head as a secondary firing mechanism

• Enhances safety because the annulus-operated portion is pressure balanced before the packer is set and the tester valve is opened

Operation

The APF-C system depends on the transfer of annular pressure through the packer down to the APF-C firing head. This pressure creates a differential pressure across the mandrel where the firing piston is housed. When the predetermined differential pressure is reached, the pins shear and the mandrel moves up and releases the firing piston, which is driven down by rathole pressure. The piston strikes the firing pin which detonates the initiator.

The operation of the drop bar or pressure-actuated firing head depends on which firing head system is used.

Annulus Pressure Firer-Control Line (APF-C)

Firing Head

HA

L1

05

15

Annulus Pressure Firer-Control Line (APF-C) Specifications

SAP No.


Maximum OD

in. (mm)

MakeupLength ft (m)





100156138 2 7/8 (73.03) 6P Acme Box × Pin

3.68 (93.47)

3.70 (1.13)

20,000(1380)

250(17)

174,000(78 900)

17,000(1170)


5-14 Firing Heads

Annulus Pressure Transfer Reservoir

The annulus pressure transfer reservoir (APTR) is an integral component of the annulus pressure firer-control line (APF-C). The APTR is the mechanism that transmits pressure from above the packer to a differential pressure or pressure-actuated firing (PAF) head on top of the perforating assembly.


• Features a full-opening ID

• Compatible with mud environments

• Adapted for RTTS and CHAMP® IV packers

• Ideal for applications that require a partial fluid column in the tubing string

• Eliminates the need for nitrogen

Operation

The APTR transmits annulus pressure into a micro-annulus created by the packer mandrel and the APTR mandrel. The pressure is ported to a control-line sub on the lower end of the packer. A stainless steel control line connects the APTR to the pressure-responsive firing head on the perforating assembly.

Annulus Pressure Transfer Reservoir (APTR)


Packer TopConnection

PackerBottomConnection

LowerControl-LineHousing

HAL

1544

0

HAL

1543

9

Annulus Pressure Transfer Reservoir (APTR) Specifications

SAP No.

Maximum OD

in. (mm)

Minimum ID

in. (mm)Top

AssemblyLower

Assembly

Length Above Packer ft (m)

Length Below Packer ft (m)


Burst Pressure psi (bars)


100156028 5.00 (50.8)

2.00 (50.8)

3 1/2 4 IF Box x

3 7/8 6 Stub Acme Pin

2 7/8 (73.03) EUE 8 Rd Box x Pin

5.09 (1.55)

1.02 (0.31)

328,000 (148 700)

18,000 (1240)

15,000 (1035)

101016453 6.12 (155.45)

2.37 (60.20)

4 1/2 4 IF Box x Pin

4 1/2 4-IF Box x 3 1/2 (88.90)EUE 8 Rd Pin

4.34 (1.32)

1.33 (0.41)

587,000 (266 200)

22,000 (1515)

19,000 (1310)

Temperature rating is determined by o-rings.These ratings are guidelines only. For more information, consult your local Halliburton representative.

Firing Heads 5-15

Slimhole Annulus Pressure Firer—Internal Control

5-in. Annulus Pressure Transfer Reservoir

The slimhole annulus pressure transfer reservoir (APTR) system assembles in a similar manner to the 7-in. and 9 5/8-in. APTR systems. Only two design changes have been implemented in the new 5-in. APTR system. First, a series of concentric tubes below the packer replaces the control line from larger APTR systems. Second, a single tube mandrel runs through the packer, replacing the series of threaded tube mandrels from the larger APTR systems.

3 1/8-in. Internal Control

Concentric tubes eliminate the need for an external control line in slimhole casing.

3 1/8-in. Annulus Pressure Transfer Reservoir—Internal Control

The slimhole 3 1/8-in. (APF-IC) firing head is designed for use with the 5-in. APTR system with internal control. The firing head design remains the same as the 3 3/8-in. APF-C with diameter reductions in many of the component parts to achieve a true 3.13-in. OD.

Slimhole Annulus Pressure Firer— Internal Control (APF-IC) Installation

Ball Valve

Safety Joint

Annular PressureTransfer Sub

Retrievable Packer

Flow Ports

Firing Head

VannGun®

Assembly

HA

L1

54

03

Slimhole Annulus Pressure Firer—Internal Control (APF-IC) Specifications

SAP No.Thread Size

and TypeMax OD in. (mm)

Min IDin. (mm)

No. of Ports


Maximum Operating Pressurepsi (bar)

Minimum Operating Pressure psi (bar)



Collapse Pressure psi (bar)

101301541 2 3/4-in. 6P Acme Box × Pin

3.13 (79.5)

1.25 (31.75) 2 56.41

(17.2)20,000 (1378)

250 (17)

87,000 (39 463) N/A 10,000

(689)

Temperature Rating 325°F (20K psi) with Extreme Environment Kit (162°C 1.406 kg/cm2 with Extreme Environment Kit)Call Technology for temperatures above 325°F (162°C).

5-16 Firing Heads

Differential Firing Head

The differential firing head (DFH) was designed to allow underbalanced perforating with a differential pressure-actuated firing system. The DFH works by requiring the internal pressure to be greater than the external pressure. This condition can be created when pressure is applied to the ID or when the OD pressure is reduced.

The pressure required to actuate the DFH may be lower than that used for other pressure-operated firing heads because it is operated by differential pressure.


• Allows underbalanced perforating in horizontal wells without a packer

• Ideal for perforating with a sucker rod or submersible pump in place

• Offers added safety because it is pressure-balanced when being run into the well

• Helps allow maximum underbalanced pressure in low-pressure wells when mechanical firing is not desirable

• Can be used when equipment or well conditions will not permit the use of high pressures

• Allows the use of time-delay elements as needed

Operation

The DFH is actuated after a predetermined differential pressure is created in the firing head ID. This differential pressure can be created when surface pressure is applied to the tubing or by reducing the hydrostatic pressure in the annulus.

When the predetermined differential pressure is reached, the shear pins holding the dog retainer piston will shear, allowing the dog retainer to move up. The upward movement releases the dogs holding the firing piston in place, and the internal pressure drives the firing piston into the initiator.

Differential Firing Head (DFH)

HA

L1

05

18

Differential Firing Head (DFH) Specifications


in. (mm)Maximum OD

in. (mm)


Maximum Operating Pressure

(differential) psi (bars)

Minimum Operating Pressure

(differential)psi (bars)




1200022622 3/8 (60.33) EUE

8 Rd Box × 2 3/8 (60.33)6P Acme Box

3.0 (76.20)

1.94(0.59)

10,000 (690)

1,000 (69)

130,000 (58 900)

20,000 (1380)

20,000 (1380)

1000142322 7/8 (73.03) EUE

8 Rd Box × 2 7/8 (73.03) 6P Acme Box

3.38 (85.73)

1.98 (0.60)

5,000 (345)

1,000 (69)

220,000 (99 700)

20,000(1380)

20,000(1380)

Temperature rating is determined by explosives or o-rings.These ratings are guidelines only. For more information, consult your local Halliburton representative.

Firing Heads 5-17

Hydraulic Actuator Firing Head and Swivel-Type Hydraulic Actuator Firing Head

The hydraulic actuator firing head (HAF) is a pressure-balanced tool that automatically fills the tubing string while it is running in the well. A stainless steel or ceramic ball is dropped from the surface or circulated into position. Pressure applied to the tubing string actuates the HAF.

The smaller swivel-type hydraulic actuator firing head (SHAF) has a swivel incorporated into the firing head assembly. The added swivel feature allows the lower portion of the firing head and the attached explosive assembly to rotate independently from the tubing string.


• Allows packerless completions

• Makes actuation easily observable

• Useful in coiled tubing conveyed completions, deviated wells, and through-tubing perforating

• Reusable

• Rotation of explosive assembly from tubing string possible with swivel type

Operation

A stainless steel or ceramic ball is dropped from the surface or is circulated downhole into the hammer piston. Pressure applied to the tubing string shears the retaining pins and forces the hammer piston into the firing pin. The firing pin detonates the initiator, which starts the detonation of the perforating assembly. Circulation is regained as soon as the firing pin has been sheared.

HA

L15384

HA

L1

05

63

Hydraulic Actuator Firing Head (HAF)

Swivel-Type Hydraulic Actuator Firing Head (SHAF)

Hydraulic Actuator Firing Head (HAF) Specifications

SAP No.


Maximum OD

in. (mm)Ball OD in. (mm)

No. and ID of Ports in. (mm)

Flow Area of Ports

in.2 (cm2)


Maximum Operating Pressure (differential)

psi (bars)

Actuating Pressurepsi (bar)

Tensile Rating lb (kg)

100156011(Swivel Type)

1.315 (33.40)NU-10 Rd Pin × 17/16 (36.51)8UN-2B Box

1.69 (42.88)

0.625(15.875)

2 @ 0.5 (12.70)

0.39 (2.52)

2.84 (0.87)

20,000 (1379)

3,200(221)

50,000 (22 680)

100156025

1.315 (33.40)NU-10 Rd Pin × 17/16 (36.51)8UN-2B Box

1.69(42.88)

0.625(15.875)

2 @ 0.5 (12.70)

0.39 (2.52)

2.18 (0.66)

20,000 (1379)

3,200(221)

50,000 (22 680)

101007031

1.90 (48.26) EUE-10 Rd 3/4 TPF Pin

2 3/8 (60.33) 6P Acme Box

2.75(69.85)

0.625(15.875)

2 @ 0.5(12.70)

0.39(2.52)

2.28(0.691)

20,000 (1379)

3,200(221)

113,000(51 256)

100156150

2 3/8 (60.33) EUE8 Rd Pin ×

2 7/8 (73.03)6P Acme Box

3.38 (85.85)

1.375 (34.925)

4 @ 1.0 (25.40)

3.14 (20.26)

2.40(0.73)

20,000 (1379)

2,000(138)

210,000 (95 254)


5-18 Firing Heads

Mechanical Metering Hydraulic-Delay Firing Head

The mechanical metering hydraulic-delay (MMHD) firing head provides a retrievable firing system with an adjustable delay for situations where longer delay times are needed. Delay time can be adjusted from 1 to 6 hours. The tool is designed with a 1/2 gallon fluid chamber below a weighted piston. The piston meters downward until it travels into a larger bore which allows it to free-fall and initiate a mechanical firing head.

Delay time is affected by temperature, tool weight above the piston, and the number of jets used (maximum of two), and the adjustments can be made by running one or two fluid metering jets or by changing the amount of fluid.


• Adjustable time-delay—May vary from 1 up to 6 hours.

• Retrievability—Firing head can be pulled and another one run without affecting the rest of the bottomhole assembly.

• Safety—With the ability to run the firing head and the guns separately, this system greatly reduces the chance of accidental or premature firing of guns.

Operation

The MMHD assembly is run into the well using normal monobore completion techniques. The mechanical metering hydraulic-delay firing head is conveyed on a slickline or electric line. For safety and flexibility, the tool will not start metering until it is landed on the top gun. Once in place and released, the firing head starts to meter. The running tools can either be pulled into the lubricator, pulled completely out of the hole, or simply pulled up the hole to a safe distance and secured to await detonation. After the guns have fired, the firing head can be quickly relatched and retrieved using the same conveyance methods as during deployment.

HA

L6

55

9

Mechanical Metering Hydraulic-Delay (MMHD) Firing Head

Mechanical Metering Hydraulic-Delay (MMHD) Firing Head Assembly Specifications

SAP No.

Maximum OD

in. (cm)

Stinger Fishing Neck

in. (cm)

Maximum StrokeLength in. (cm)

Maximum Metering Stroke* Length

(Available for Delay)in. (cm)

Overall Length*

(Extended) ft (m)


(differential) psi (bars)

Temp Rating °F (°C)


Total Volume (Silicon)gal (liter)

Assembly Weight lb (kg)

101201927 Dependent on centralizers

1.75 (4.45)

54.86 (139.34)

46.50 (118.11)

12.44 (3.79)

13,000 (896.6)

350 (176.67)

51,100(23 100)

1/2 (1.89)

152 (68.95)

* Length from top sub to firing head body (does not include weight bars and/or skirt)Delay time of 1 hour minimum is recommended for safe operation of system.Delay time of 6 maximum hours is dependent on temperature, silicon fluid, and number of jets.These ratings are guidelines only. For more information, consult your local Halliburton representative.

Firing Heads 5-19

Slickline-Retrievable Mechanical Firing Head

The slickline-retrievable mechanical firing head (SLRMFH) is designed to give customers flexibility in completing a well. It can be run attached to the guns, separately from the guns, or using an auto-release firing mechanism. The firing head latches onto the guns and provides a positive indication that it is attached. The SLRMFH can be retrieved if the firing head needs to be replaced.

The system can be run with either a mechanically operated firing head or a pressure-operated firing head. It is designed so that 80% of the parts are used in all three applications allowing for more flexibility with less inventory.


• Saves rig time—If for any reason the firing head needs replacement, the guns remain in the hole and the firing head can be retrieved.

• Positive engagement—When the firing head is run separately, the operator can tell when the firing head is latched onto the guns.

• Safety—Guns can be run separately from the firing head adding a safety feature for the guns at the surface.

• Flexibility—Guns can be run separately or attached. Unlimited number of runs can be made to replace firing head if needed.

Operation

The SLRMFH was designed for 3 1/2- and 2 7/8-in. tubing strings. It can be run with either a mechanical drop firing head, or a pressure-operated firing head such as the 1 11/16 time-delay firer (TDF).

The top gun is assembled with the J-slot stinger. The guns are run into the well on tubing and then correlated on depth. The running tool is latched to the firing head at surface and run in on wireline/slickline.

As the firing head is lowered, it comes in contact with the J-slot stinger. The skirt on the firing head then automatically latches into position connecting the firing head with the J-slot stinger. An overpull is applied to give a positive latch indication. The running tool is released by jarring down and the slickline is pulled out of the well. The guns are fired by pressure or mechanical means.

The firing head can be retrieved by relatching to the firing head and jarring up. The jarring action shears the brass screws freeing the firing head from the J-slot stinger. If the firing head does not actuate, another firing head may be run as many times as required.

Slickline-Retrievable Mechanical

Firing Head (SLRMFH)

HA

L6

56

0

5-20 Firing Heads

Slickline-Retrievable Mechanical Firing Head (SLRMFH) Specifications

SAP No.

Maximum OD

in. (cm)

Minimum ID

(No-Go)in. (cm)

Overall Length (Max)ft (m)


Minimum Operating Pressurepsi (bars)

Minimum Operating Pressure

Auto Releasepsi (bars)

Maximum Differential Pressure

Auto Releasepsi (bars)

Tensile Strength

of FH Body lb (kg)

Maximum Sustained

Force Required to Shear Two

Lugslb (kg)

Weightlb (kg)

w/ Model III-D

Mechanical FH

101226902 2.31 (5.87)

1.56 (3.96)

20.05(6.11)

8,000(550)

250(17.2) N/A N/A 30,000

(13 600)4,000(1800)

120 (54.4)

w/ Pressure Actuated FH 101227170 2.31

(5.87)1.56

(3.96)20.05 (6.11)

17,000 (1170)

2,200 (150) N/A N/A 30,000

(13 600)4,000(1800)

100 (45.4)

w/ Model III-D

Mechanical FH and Auto

Release

101227212 2.31 (5.87)

1.56 (3.96)

20.05(6.11)

8,000 (550)

250 (17.2)

1,500 (100)

10,000 (690)

30,000 (13 600)

4,000(1800)

120 (54.4)

Burst and collapse pressures are determined by tubing.Temperature rating is determined by explosives. These ratings are guidelines only. For more information, consult your local Halliburton representative.

Firing Heads 5-21

Slickline-Retrievable Time-Delay Firer Firing Head

The slickline-retrievable time-delay firer (TDF) firing head is a combination of two assemblies: the slickline-retrievable firing head and a 1 11/16-in. TDF firing head. It is a pressure-actuated firing head with a built-in pyrotechnic time-delay assembly.


• Allows the guns to be run in the hole without any type of firing mechanism installed

• Allows the retrieval and reinstallation of a malfunctioning firing head without pulling the guns

• Allows greatly reduced actuating pressures of the firing head because the firing head does not have to be in place when the guns are run

Operation

This firing head does not have to be run until after all pressure testing has been done and the heavy fluids have been displaced, which allows a reduced actuating pressure for the firing head.

This assembly allows the operator to run guns in the hole on the end of tubing without a firing head. This assembly can be run in on slickline and attached to the firing head after the tubing is in the hole. It can also be retrieved on slickline. H

AL

15

38

5

Slickline Retrievable Time-Delay Firer (TDF) Firing Head

Stinger AssemblyH

AL15

434

1 11/16-in. Slickline-Retrievable Time-Delay Firer (TDF) Firing Head Specifications

SAP No.Maximum OD

in. (mm)

Overall Length (1 fuse)

ft (m)

Additional Length per Fuse

ft (m)

Temperature Rating°F (°C)

MaximumOperating Pressurepsi (bars)



100155739 1.688(42.88)

3.83(1.17)

0.87(0.27)

425 for 100 hours(218 for 100 hours)

17,000(1170)

2,200(150)

23,000(1590)

The assembly certification sheet which specifies the batch number and pin values is supplied with each assembly.

3 3/8-in. Vann™ Jet Stinger Specifications

SAP No.


Maximum OD

in. (mm)

Minimum ID (No-Go)in. (mm)

Makeup Length with

2-ft Subft (m)



Tensile Strength

(FH Body)lb (kg)

Weight with 2-ft Sublb (kg)


3.38(85.85)

1.37(34.80)

5.37(1.64)

20,000(1380) None 238,000

(107 900)73

(33)Burst and collapse pressures are determined by handling sub.Temperature rating is determined by explosives.

5-22 Firing Heads

Extended Delay Fuses

A delay fuse is an explosive device with a slow-burning fuse. Extended and modular delay fuses add time between the actuation of the firing head and the actual detonation of the guns. Each delay fuse lasts six minutes at 70°F.


• Increases delay time when nitrogen is used to actuate the firing head to give additional time to bleed the nitrogen pressure down to the desired level

• Allows time for necessary actions to take place downhole such as increasing pressure to open a pressure-actuated vent assembly

Operation

The extended delay assemblies contain one delay fuse and can be run with any other firing assembly. They are installed between the firing head and the guns.

The modular delays are assembled with the firing head in one housing and become an integral part of the firing system. The modular delays are used primarily with the multiaction-delay firing head, the 1 11/16-in. time-delay firer (TDF) firing head, and the slickline-retrievable TDF firing head.

Extended Delay Fuses

Assembly

HA

L1

53

83

Extended Delay Fuses Specifications


in. (mm)

Maximum OD

in. (mm)



psi (bars)

Temperature Rating Delay Fuse

°F (°C)



100005229 2 (50.8) 6P Acme Box × Pin 2.5 (62.5)

1.10 (0.34)

25,000 (1725) 425 (218) for 200 hours 197,000

(89 300)30,000 (2070)

100009426 2 7/8 (73.03) 6P Acme Box × Pin 3.375 (85.73)

1.10 (0.34)

25,000 (1725) 425 (218) for 200 hours 270,000

(122 400)30,000 (2070)

These ratings are guidelines only. For more information, consult your local Halliburton representative.

Firing Heads 5-23

Modular Mechanical Firing Head

The modular mechanical firing head is designed to be a retrievable firing system utilizing a standard mechanical firing head with a specialized drop bar for detonation. This system will allow the operator the flexibility to run the gun assemblies independently of the firing system. Once the guns are in place, the firing head is set on the top module and released. The perforation assembly is detonated by use of a special fluted bar dropped from surface.

The most common application for this system is to be run with the modular guns in a monobore completion. Special consideration must be given to job set-up and execution to ensure that this tool functions properly.


• Safety—With the ability to run the firing head and the guns separately, this system helps to greatly reduce the chance of accidental or premature firing of the guns.

• Retrievability—In the event of a mechanical malfunction, the firing head can be pulled, and another one run without interfering with the rest of the bottomhole assembly.

Applications

The modular mechanical firing head is designed to be run on slickline and set on the top gun in a monobore completion by use of a JDC hydraulic running tool. The system is designed with the hammer held above the firing pin with brass shear screws. The two shear screws are rated at 875 lb each. The tool is actuated by dropping a specifically designed drop bar fitted for the proper casing. (Do not use a standard 1 1/4-in. drop bar.) The bar strikes the stinger with sufficient force to shear the brass screws and drive it into the firing pin.

The firing pin and hammer are pressure balanced; and therefore, are not limited to any specific depth and/or hydrostatic pressure beyond the tool specifications. Modular Mechanical

Firing Head

HA

L8

32

5

5-24 Firing Heads

Modular Mechanical Firing Head Specifications

SAP No.

Stinger Fishing Neck 2-in.

Stingerin. (mm)

Stinger Fishing Neck 2 1/2-in.

Stingerin. (mm)


psi (bars)Tensile Strength

lb (kg)Overall Length*

in. (mm)

Maximum Stroke Length

in. (mm)

Shear Rating For Brass

lb (kg)

120021629 1.38(35.05)

1.75(44.45)

13,000(896.6)

59,000(26 762)

72.30(1836.42)

7.88 (200.15)

1,700(771)

*Will vary with skirtMaximum OD dependent on centralizers used.Temperature rating is determined by explosives.Weight dependent on centralizers and skirts.

Drop Bar Options

SAP No.

Casing and Tubing Size and Weight

in./lb (cm/kg)Casing IDin. (mm)

Total Bar OD

in. (mm)

N/A 2 7/8 / 6.4(7.30 / 2.9)

2.441(62.0) N/A

101227709 3 1/2 / 9.2(8.89 / 4.17)

2.992(76.0)

2.50(63.5)

120125486 4 1/2 / 9.5-13.5(11.43 / 4.3-6.12)

4.090(103.9)

3.75(95.3)

101227719 5 / 15-18(12.7 / 6.80-8.16)

4.408(111.9)

4.125(104.8)

101227720 5 1/2 / 15.5-23(13.97 / 7.03-10.43)

4.950(125.7)

4.50(114.3)

Skirt-Centralizer Selection Chart

SAP No.Skirt ODin. (mm)

Centralizer ODin. (mm)

101207195 2(50.8) N/A

101201882 2.5(63.5)

3.00(76.2)

1012071873.50

(88.9)101207198

3.75(95.3)

100014297

101228625 2 3/4(69.9)

3.25(82.6)

1012130873.50

(88.9) 100014299

101201884 3 1/8(79.4)

3.875(98.4)

101207193

101226987 3 3/8(85.7)

3.75(95.3)

1000095814.00

(10.16) 100156785

4.40(111.8)

100010177

101205671 4 5/8(117.4)

5.61(142.5)

1001562245.75

(146.1) 100156225

Firing Heads 5-25

HalSonics® Firing Head

The HalSonics® firing head system is designed to actuate tubing conveyed perforating guns and may be conveyed by tubing, slickline, or electric line. This system can overcome obstacles in jobs where bar-drop or pressure actuated firing heads are not technically feasible or economically practical to detonate the downhole perforating assembly.

In addition, this system can be utilized when extensive well fluid manipulations are required or where multiple pressure cycles are performed prior to perforating. The HalSonics firing head is also ideal for applications where extremely long delay times are required with traditional delay type firing systems.


• Zone 1 rated

• Designed to eliminate detonation at the surface

• Precisely controlled signal sequence

• Remote actuation of TCP guns

• Can be run offshore or on land

• Can transmit through nitrogen or air cushion

• Can be run above or below the guns

• Ideal for highly deviated wells

• Ideal for wells with existing perforations

• Wells where nitrogen is cost prohibitive

• Selective perforation intervals

• Wells with casing pressure limitations

• Small surface equipment footprint

• Can utilize redundancy to actuate the gun system

HalSonics® Firing Head

HA

L1

46

03

5-26 Firing Heads

Firing Heads 5-27

Operation

With the guns at depth, the pressure pulse unit is easily attached to the wellhead. On the operator’s command, the surface control unit sends the pressure pulse unit a precisely controlled signal sequence. Using air or nitrogen, the pressure pulse unit then sends a coded signal to a downhole receiver. Once the signal has been decoded, the controller begins pulling an actuating rod. When the actuating rod has

retracted, retaining lugs are released and a pressure port opens, allowing hydrostatic pressure to act on the piston.

Powered by the hydrostatic pressure, the piston strikes the firing pin, actuating the TCP guns.

HalSonics® Firing Head Specifications


Maximum OD

in. (mm)

MinimumID

in. (mm)


Minimum Operating Pressurepsi (bar)

TemperatureRating °F (°C)

Downhole Battery Life

Depth Range ft (m)

Downhole Tool Overall

Lengthft (m)

Downhole Tool Weight

lb (kg)

2 7/8 in. EUE 8RD × 3 3/8

Gun Connection

3.7 (93.98) N/A 15,000

(1030)250 (17)

300 (150) 200 hr

Tested to 17,000 (5100)Designed for 30,000 (9100)

15 (4.57)

230 (104.33)


5-28 Firing Heads

Side-Pocket Mandrel Firing Head

The side-pocket mandrel firing head (SPMFH) is designed for well conditions that preclude the use of a pressure-actuated firing head run with a Y-block. The side-pocket mandrel firing system is used on single-string, multizone completions and standard dual completions. A modified model III-D mechanical firing head is attached to the short string side of a side-pocket mandrel. The firing head is detonated with a kickover tool run on slickline.


• Selectively fires multiple intervals

• Eliminates the need for nitrogen

• Allows maximum underbalance for low-pressure formations

• Helps provide safety because the firing head is designed to eliminate detonation

• Offers economical value

Operation

The model III-D mechanical firing head is made up on the short string side of the side-pocket mandrel. When the perforating assembly is ready to be detonated, the operator runs a kickover tool down the long string on slickline. After the kickover tool is located in the side-pocket mandrel, the slickline operator jars down. The kickover tool hits the releasing pin on the model III-D. The firing piston is forced into the initiator by the hydrostatic pressure in the tubing string to detonate the VannGun® assembly.

HAL

1545

3

Side-Pocket Mandrel Firing Head (SPMFH) Specifications

SAP No.

Thread Size and Type(Long string side)

in. (mm)Maximum OD

in. (mm)Minimum ID

in. (mm)

Overall Lengthft (m)

100155737(Firing Head)

1.90 (48.26) EUE 10 Rd Pin × 2 3/8 (60.33) 6P Acme Box

2.75 (69.85) N/A 2.36

(0.72)

221.00284(7-in. Side-Pocket

Mandrel)

2 3/8 (60.33) 4.7 lb OECO-B Box × Box

5.54 (140.72)

1.926 (48.92)

5.79 (1.76)

221.00285(9.625-in. Side-Pocket

Mandrel)

2 3/8 (60.33) 4.7 lb OECO-B Box × Box

6.62 (168.15)

1.926 (48.92)

5.79 (1.76)

101306060 3 1/2 CJ Hydril 8.00 (203.20) N/A N/A


Side-Pocket Mandrel Firing Head (SPMFH)

Firing Heads 5-29


The annulus pressure crossover assembly (APCA) allows the use of annulus pressure to actuate any one of several firing heads. This assembly is compatible with retrievable packers of all types and sizes.


• May be used as the annulus firing system on wells with non-full-opening test tools and a partially filled drillstring

• May be used as the annulus firing system on horizontal wells

• Allows the use of below-packer venting devices along with this assembly

Note: Not recommended for mud environment

Operation

The APCA creates a pressure chamber above the firing head that is equalized with the pressure in the casing annulus. Once the packer has been set, the pressure on the annulus can be increased to actuate a pressure-actuated firing head. The pressures in the annulus and the tubing can also be manipulated to create the differential pressure necessary to actuate a differential-type firing head.

Annulus Pressure Crossover Assembly (APCA)

Annulus PressureCrossover Assembly

Packer

Ported Sealing Sub

Tubing

Time-Delay Firer

VannGunAssembly

®

HAL

1544

9

HAL

1544

8

Annulus Pressure Crossover Assembly (APCA) Specifications

SAP No.


Maximum OD

in. (mm)Minimum

IDFlow Areain.² (cm²)

Minimum Makeup Length ft (m)


Maximum Differential Pressurepsi (bars)


Burst Pressurepsi (bars)


100014175 2 3/8 (60.33) EUE 8 Rd

3.56 (90.42) Non-fullbore 2.25

(14.52)9.15

(2.79)12.35 (3.76)

16,000(1100)

190,000 (86 200)

27,000 (1860)

16,000 (1100)

100155786 2 7/8 (73.03) EUE 8 Rd

5.0(127) Non-fullbore 4.75

(30.65)9.40

(2.87)12.60 (3.84)

16,000(1100)

270,000 (122 400)

22,000 (1515)

16,000 (1100)

Maximum operating pressure is determined by tubulars.Temperature rating is determined by explosives.These ratings are guidelines only. For more information, consult your local Halliburton representative.

5-30 Firing Heads

EZ Cycle™ Multi-Pressure Cycle Firing Head

The EZ Cycle™ firing head is a pressure-operated tool that can be cycled several times prior to firing the perforating guns. Several pressure operations can also be performed on the well including tubing testing, packer setting and packer testing prior to firing the perforating guns. Even if pressure operations are higher than the operating pressure of the firing head, the EZ Cycle firing head should not fire until it has completed all of the preset cycles. The firing head is cycled by applying pressure at the tool to overcome a nitrogen-charged chamber which operates the cycling piston back and forth until the entire release rod has been pulled from the piston collet.

Each EZ Cycle firing head assembly includes a nitrogen chamber, cycling grapple piston, and firing piston with firing pin initiator assembly.


• Ideal for completions and drillstem testing

• Time-delay elements can be used as needed for delay time

• Can be used in underbalanced or overbalanced perforating jobs

• It is a surface-safe firing head because it requires pressure to energize the firing piston

• Operates at low pressure

• Can be deployed connected to the gun assembly or run separate on slickline or coiled tubing

• Allows the retrieval and reinstallation of a malfunctioning firing head without pulling the guns

• Can be used when equipment or well conditions will not permit the use of high pressures

EZ Cycle™ Firing Head Assembly

HA

L1

40

95

Firing Heads 5-31

Operating the EZ Cycle™ Firing Head

The tool is run in hole with a pre-charged nitrogen chamber, which is set according to the maximum bottomhole pressure. After positioning gun on depth and all operations prior to firing guns have been completed, the firing head is cycled to detonate the perforating guns. Pressure applied at the tool will move the cycle piston and traveling grapple up 0.375 in. pulling the release rod up 0.375 in. Releasing the applied pressure will allow the nitrogen charge to move the cycle

piston and traveling grapple down engaging another 0.375 in. of the release rod. These steps are continued until the release rod is completely retrieved from the firing piston collet. At this point, the bottomhole pressure will drive the firing piston into the firing pin detonating the initiator and the guns.

3.00 in. Multi-Pressure Cycle Firing Head Assembly Specifications

Upper Connection (External Fishneck)in. (cm)

Lower Thread Size

and Type in. (cm)

Makeup Length

in. (cm)

Maximum OD

in. (cm)

Minimum ID

in. (cm)


Operating Pressure Range psi (bar)

Tensile Rating* lb (kg)

Burst Pressure* psi (bar)

Collapse Rating* psi (bar)

2.313 (5.875)

2 3/8 (6.0325) 6P Acme Box

77.32 (83.36)

3.00 (7.62) N/A 400 (204.4)

Low Pressure Assembly

High Pressure Assembly

100,000 (18 143)

40,000 (1379)

40,000 (1379)1,000-5,000

(68.95-344.74)

5.000-20,000

(344.74-1378.95)

* Call your local Halliburton representative or email us at [email protected] if conditions exceed this value.

5-32 Firing Heads

Special A

pplications

Special Applications

DrillGun™ Perforating Systems (page 3)

The DrillGun™ perforating system combines rugged, reliable Halliburton perforating components with the versatility of drillable materials. The DrillGun system allows running and setting the squeeze packer and perforating gun in one run, eliminating the need for wireline perforating in many cases.

Select Fire™ Systems (page 5)

The Select Fire™ system lets you perforate zones in any order selected. The system provides the ability to perforate multiple zones individually during a single trip.

Isolation Sub-Assembly (page 6)

The isolation sub-assembly (ISA) is live well intervention technology designed to provide extreme flexibility in well completions. ISA allows completion or recompletion of the well without killing it. The well can be producing before, during, and after the guns are deployed in or out of the well.

AutoLatch™ Release Gun Connector (page 7)

The AutoLatch™ release gun connector joins VannGun® assemblies and enables VannGun sections to be run in and out of new or live wells.

Ratchet Gun Connector (page 8)

In addition to perforating new wells, the Halliburton ratchet gun connector system is ideal for reperforating producing wells since the well does not have to be killed and can be left on production. It also allows perforating with all production equipment in place.

Shearable Safety Sub (page 9)

The shearable safety sub is designed to provide a gap in the explosive train which could be severed at surface with the shear rams. It is most commonly used in live well intervention.

Modular Gun System (page 10)

Through a special arrangement of perforating equipment, Halliburton’s patented modular gun system permits the optimum number of guns to be removed via slickline or E-line so larger intervals can be perforated simultaneously. Halliburton perforating specialists know the equipment, know the well, and know the best techniques to fit your particular application.

Auto-Release Gun Hanger (page 12)

One of the main features of the modular gun system is the auto-release gun hanger. For high volume testing and production, the auto-release gun hanger allows a zone to be perforated and tested with virtually no downhole restrictions.

Setting Tools for Auto-Release Gun Hanger (page 14)

The running and retrieving tools for the modular gun system and the auto release gun hanger gives customers flexibility in the conveyance of these tools in the well.

Detach™ Separating Gun Connector (page 15)

The Detach™ separating gun connector allows operators to deploy long gun sections into the well. The guns are deployed downhole in a single trip and placed across the perforating zone supported by a gun hanger or plug. The guns are fired when desired and then, will automatically separate, which allows them to be retrieved in manageable sections or left in the hole.

G-Force® Precision Oriented Perforating System (page 16)

The G-Force® system features an internal orienting charge tube assembly and gun carrier, which allows perforating in any direction, irrespective of the gun’s position relative to the casing.

Special Applications 1Special Applications 6-1

Explosive Transfer Swivel Sub (page 18)

The explosive transfer swivel sub allows two sections of guns to rotate independently of one another. Such independent rotation is important on long strings that must be oriented in a specific direction in horizontal wells.

Eccentric Orienting Tandem (page 19)

Eccentric subs allow perforating guns to be oriented in situations where the fin system is not ideal due to restrictions in the casing, fishing concerns, welding concerns, etc.

Roller Tandem Assembly (page 20)

Roller tandem assemblies are used to reduce the friction between the perforation guns and the casing. In some cases, the frictional drag can be reduced by as much as 90%.

Centralizer Tandem (page 21)

For operations where it is desirable to centralize the guns and other tools in the casing, Halliburton has designed a full range of centralizers for all gun sizes.

StimGun™ Assembly (page 22)

The StimGun™ assembly has been used with great success in conventional underbalanced perforating to obtain benefits of both extreme overbalance from propellants and the surging effect from maximum underbalance. The StimGun assembly is a process that combines perforating and perforation breakdown with a propellant in a single tool and operation.

StimTube™ Assembly (page 24)

The StimTube™ assembly process uses the same solid propellant technology employed by StimGun to simulate existing perforations, slotted liners, or openhole sections when it is not desirable to add perforations.

PerfStim™ Process (page 26)

The PerfStim™ process combines perforation and stimulation operations in one step by driving a fluid spear into the formation at high flow rates and pressures the instant after perforating.

POWR*PERFSM Perforation/Stimulation Process (page 27)

POWR*PERFSM perforation/stimulation process is a completion process that uses proven extreme overbalance perforating techniques. This method is coupled with the release of an erosive agent at the moment of VannGun® detonation to clean and scour near-wellbore damage and enhance conductivity of fractures created by extreme overbalance perforating.

Quick Torque™ Connector (page 28)

The Quick Torque™ connector consists of connectors that cover both ends of each gun section to enclose the assembly. The connectors have a common, self-aligning drillpipe thread that allows automatic or manual make-up. Explosive transfer occurs through a web, making the system self-contained and totally safe. With these connectors, TCP gun assemblies can now be picked up by the rig equipment and properly made up using iron roughneck equipment, without the need for human intervention. It simplifies the process and saves time by eliminating assembly of the components on the rig.

Pump Through Firing Head (page 30)

The 1 11/16-in. pump through firing head is designed to be run on coiled tubing and is used for breaking the ceramic flapper valve disk on a one-trip coiled tubing operation.

POWR*PERF, a process of Marathon Oil Company, is licensed by Halliburton. POWR*PERF is a service mark/trademark of Marathon Oil Company and licensed by Halliburton.StimTube™ and StimGun™ are trademarks of Marathon Oil Company. PerfStim™ is a trademark of Oryx Energy Company. Patented by Oryx and licensed by Halliburton.

2 Special ApplicationsSpecial Applications 26-2 Special Applications

DrillGun™ Perforating Systems

HAL

1205

6

Halliburton has developed the DrillGun™ assembly to be a drillable perforating system that provides reliable, quality performance while lowering overall wellsite costs by:

• Eliminating the high costs associated with wireline services

• Eliminating the need to switch to a mud system for workovers

The DrillGun perforating system is a new method that combines rugged, reliable Halliburton perforating components with the versatility of drillable materials. It is this type of innovative design that has made Halliburton the leader in perforating charge performance and delivery systems. Now, with the DrillGun perforating system, you have a drillable, disposable system that helps save you two of the most valuable commodities at the wellsite—time and money.

Components of the drillable perforating system are the drillpipe conveyed to the zone of interest; thereby eliminating mobilization or demobilization charges normally associated with wireline units. And, since no mud system is needed, clear fluids can remain in place for workover operations. Once in place, the firing head is actuated by pressure applied through the tubing. After perforating, the gun can be drilled out with conventional drilling methods.

The drillable perforating system is ideal for:

• Single-trip perforating, packer placement, and cementing on tubing

• Cementing and perforating in underbalanced conditions

• Plug-to-abandon operations

• Workover cementing with clear fluids

• Plugback set on wireline

• Limited entry drill stem testing

Components of the drillable perforating system include:

• Aluminum perforating gun

• High-performance, perforating charges

• Halliburton’s industry-proven EZ Drill® SVB packer

DrillGun™ Assembly


DrillGun™ Perforating System - Quick, Economical Solution For Perforating In Unusual Conditions.

Savings on Rig Time

Operator's challenge—Carrizo Oil & Gas, Inc. needed to perform a squeeze job on a South Texas well. The customer had already switched to a lighter drilling fluid and did not want the high cost of changing to a mud system. As a result, the well would have to be perforated underbalanced.

Halliburton's solution—To meet this challenge, Halliburton recommended its DrillGun system.

Economic value created—As a result, Carrizo was able to perform the squeeze job without having to replace the lighter drilling fluid with an expensive mud system. This procedure saved rig time and the expense of a fluid change for a total economic value to the customer of $20,000.

Block Squeeze Application

Operator's challenge—An operator working in the Permian Basin had to perform three block squeezes in a 7 5/8 in. liner from 14,400 ft to 14,800 ft. A primary cement job had not been possible, so instead of cement behind the casing, there was 15.5 ppg drilling mud. The well fluid was 10 ppg brine water. However, it would not be necessary to change the well fluid to 15.5 ppg drilling mud to cement.

Halliburton's solution— Halliburton logged the first DrillGun system on depth, perforated and performed the cement job at 4,230 psi underbalanced. For the next two DrillGun system runs, we tagged the first retainer and located it on depth to perform the squeeze.

Economic value created—The three aluminum perforating guns added only one hour each to the drill-out time. The customer estimates that this procedure saved $52,000.

Plug-to-Abandon

Operator's challenge—To plug a well before abandoning it, an operator in Chambers County, Texas needed to perforate six zones.

Halliburton's solution—Halliburton recommended using its DrillGun rather than employing electric-line perforators which would normally be selected for the project. The first DrillGun system was started in the well on Sunday evening and was set the next day at a depth of 13,050 ft. The bottom zone was then squeezed. After the procedure was completed, the setting assembly was pulled out of the hole. It went back in with the second stage, and the job was performed at 8,590 ft. The next day, the final four jobs were run at 5,500 ft, 2,615 ft, 500 ft, and 350 ft, respectively.

Economic value created—All six stages were completed in 2 1/2 days. If electric-line perforators had been used, the total job would have taken up to six days. By using the Halliburton DrillGun system, the operator saved four days of rig-associated costs, consultants, and fluid standby time. An additional savings was realized by using the perforating DrillGun system instead of more expensive electric-line charges. The resulting estimated economic value

to the customer is $24,200.

DrillGun™ Assembly Specifications

SAP No.Thread Size

and TypeMaximum OD

in. (mm)




MaximumOverall Length

ft (m)

101288693Aluminum

2 7/8-in. EUE 8 Rd73.03 mm EUE 8 Rd

4.00(101.6)

14,500(1000)

3,500(241)

300 (148.9)*

4.40(1.341)

101288692Aluminum


7.00(177.8)

14,500(1000)

3,500(241)

300 (148.9)*

4.40(1.341)

101292015Composite


3.625(92.1)

14,500(1000)

3,500(241)

300 (148.9)*

3.95(1.204)

* For use in wells above 300°F (148.89 °C), consult a Halliburton representative.



The Select Fire™ system offers flexibility in perforating, testing, and evaluating multiple zones in one trip. The Select Fire system saves rig time and tool charges to help multiply profits.

Features

• Perforating and testing several individual zones — one at a time

• Selecting the order zones are perforated

• Customizing gun configurations for various applications

• Available for all VannGun® assemblies 2-in. and larger

Benefits

Air

Chamber

TDF Firing

Head

VannGun

Assembly

®

Air Chamber

Select Fire™

Sub

Sealed Initiator

Pressure

Isolation

Sub

VannGun

Assembly

®

HA

L1

05

86

• Helps develop essential information about the reservoir — potentially saving hundreds of thousands of dollars

• Saves rig time and tool charges to help multiply profits

Select Fire™ Sub Operation

Select Fire™ Tubing Conveyed Perforating System

AIR

C

H

A

M

B

E

R

P

R

E

S

S

U

R

E

Before Firing

When gun #1 fires, theexplosives train is continuedto the Select Fire™ Sub, which firesa shaped charge downward.

Pressure may now enter intothe air chamber. (Note: theisolation sub is used toprevent pressure from goingupward from the Select Fire Sub).

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The isolation sub-assembly (ISA) is live well intervention technology designed to provide extreme flexibility in well completions. The ISA allows completion or recompletion of the well without killing it. The well can be producing before, during, and after the guns are deployed in or out of the well.

The ISA is a lower cost alternative to other live well intervention assemblies. The ISA incorporates a threaded connection that is manually connected and disconnected.

Features

• Can run VannGun® assemblies on hydraulic workovers, coiled tubing, or wireline

• Can run VannGun sections to perforate a new well or add perforations to existing zones

• Do not have to kill well to run or retrieve guns

• Can perforate underbalanced or overbalanced

Benefits

• Low cost

• Provides extreme flexibility in well completions


Gun

IsolationSub-Assembly

Gun

SealingInitiator

SealingArea

SealingInitiator

HA

L6

15

1

Isolation Sub-Assembly Specifications

SAP No.

Thread Size and Type in. (mm)

OD Isolation Sub-Assembly with OD Ram

Lockin. (mm)

Maximum OD

in. (mm)




1012283961 11/16-in. 8P Stub Acme 2G

(42.86)

2 with 1 1/2(50.8 with 38.1)

2.015 (51.18)

2.42(0.74)

10,000(689)

64,500(29 250)

1012222742 3/8 6P Acme

2G(60.33)

2 3/4 with 2(69.85 with 50.8)

2.765(70.23)

2.28(0.69)

10,000(689)

108,000(49 000)

1012263302 7/8 6P Acme

2G(73.03)

3 3/8 with 2(85.73 with 50.8)

3.395(86.23)

2.22(0.68)

10,000(689)

191,400(86 800)

Temperature rating is determined by explosive.These ratings are guidelines only. For more information, consult your local Halliburton representative.



The AutoLatch™ release gun connector is designed to join VannGun® assemblies and enables VannGun sections to be run in and out of new or producing wells.

Using the AutoLatch system, VannGun assemblies are connected without rotation and can be operated with standard blowout preventer (BOP) rams, making this connector ideal for snubbing guns into and out of the wellbore with coiled tubing or a hydraulic workover (HWO) unit.

The AutoLatch connector can also be used to run VannGun assemblies on wireline when the length of the perforating assembly is limited by the lubricator length. The VannGun assemblies can be run in sections (limited by the weight rating of the wireline) and then, retrieved in sections. This system reduces the number of wireline runs to perforate longer intervals.


• Can be used to perforate new or existing wells

• Can snub VannGun assemblies into and out of the well

• Utilizes standard BOPs

• Can be used with coiled tubing, HWO, or wireline

• Can retrieve VannGun assemblies without killing a producing zone

• Can perforate in underbalanced or overbalanced conditions

• May be used for monobore completions

• Can be used when oriented perforations are required

• Sections are quickly connected for time savings.

• Can be designed to accommodate different BOP configuration


Collet Fingers

Stop/ReleasePads

Spring Housing

Operating Spring

Shear Screws

Stinger Assembly

Collet RetainerHousing

OD Seal Area

Pressure IsolationConfiguration

HA

L8

66

2

AutoLatch™ Release Gun Connector Specifications

SAP No.


in. (mm)

Maximum OD

in. (mm)

Makeup Lengthft (m)



1012058662 3/8 6P Acme

Box × Pin(60.33)

2.88(73.15)

4.46(1.36)

20,000 (1380)

80,000 (35 000)

1001557752 7/8 6P Acme

Box × Pin(73.03)

3.625 (92.00)

3.47(1.06)

20,000 (1380)

125,000 (56 800)

Temperature rating is determined by explosives.These ratings are guidelines only. For more information, consult your local Halliburton representative


Ratchet Gun Connector

In addition to perforating new wells, Halliburton’s ratchet gun connector system is ideal for reperforating producing wells since the well does not have to be killed and can be left on production. It also allows perforating with all production equipment in place. Connections are made inside the lubricator using a left-hand quick connect locking mechanism.


• Can be snubbed into and retrieved from a live well

• Utilizes standard BOPs

• Can perforate long and multiple intervals in a single trip

• Does not have to kill producing zone to run or retrieve guns

• Perforates new wells

• Reperforates producing wells with all production equipment in place

• Perforates underbalanced or overbalanced assemblies

• VannGun® sections are quickly connected together.

• Can be used with HWO

Ratchet Gun Connector

Upper RatchetGun ConnectorAssembly

Ratchet Sleeve

Shear Pins

Left-HandConnection

Seal RamSlip Area

Lower RatchetGun ConnectorAssembly

Firing Pin

Sealed Initiator

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Ratchet Gun Connector Specifications

SAP No.


in. (mm)Maximum OD

in. (mm)Makeup Length

ft (m)



1010007942 3/8 6P Acme

Box × Pin(60.33)

2.35(59.69)

2.11(0.64)

13,000(896)

100,000(45 360)

1010007932 7/8 6P Acme

Box × Pin(73.03)

3.375 (85.73)

2.11(0.64)

13,000(896)

220,000(100 000)

Temperature rating is determined by explosive.These ratings are guidelines only. For more information, consult your local Halliburton representative.


Shearable Safety Sub

The shearable safety sub is designed to provide a gap in the explosive train, which could be severed at surface with the shear rams. The most common application is in the use of live well intervention.

The shearable safety sub provides two levels of defense against wellbore pressures. First, it provides a sub with a smooth profile that is utilized by closing the sealing rams to control pressure when the gun connection is made up or broken out. Secondly, if the well conditions become dangerous and the shear rams need to be activated, it provides an area in the gun assembly that does not contain explosives and can be safely severed by the shear rams.

Features

• Continues the explosive train without use of continuous explosives

• Isolates pressure from below

• Allows a smooth sealing area for the pipe rams to seal against

• Uses standard explosives

• Contains standard 3 3/8-in. gun connections above and below

Benefits

• Can be run with tubing, coiled tubing, wireline, and modular applications

• Can be sheared independently of the guns firing

• Can be redressed at minimal cost

This tool has been successfully sheared during testing using the following:

• Shaffer shear 7 1/16-in. 10k safety head

• Piston diameter of 14 in. (153 in.2)

• Sheared at 2,000 psi

• Force required to shear tool = (153 in.2) (2,000 psi) = 306,000 lb

Shearable Safety Sub

HAL

1545

4

Shearable Safety Sub Specifications


Maximum ODin. (mm) Minimum ID

Makeup Lengthft (m)




Weightlb (kg)

2 7/8-in. AcmeBox x Pin

3.375(85.73) N/A 2.50

(0.76)20,000(1380) N/A 200,000

(90 700)54.4

(24.6)

Temperature rating is determined by explosive.


Modular Gun System

Through a special arrangement of perforating equipment, Halliburton’s patented modular gun system permits the optimum number of guns to be removed via slickline or electric line so larger intervals can be perforated simultaneously. In fact, the modular gun system is so innovative, Halliburton has patented* this unique system, proving once again our commitment to bring the latest technology to the wellsite.

The modular gun system is run by Halliburton perforating specialists who know the equipment, know your well, and know the best techniques to fit your particular application. And of course, the modular gun system is backed by Halliburton’s worldwide network of technical support, reliable equipment, and innovative performance—all of which are ready to go wherever and whenever needed.


RetrievableFiring Head

(WirelineConveyed)

Wireline

Running Tool

Stinger Skirt

Stinger

Centralizer

Auto-ReleaseGun Hanger

HAL

6093

• Ideal for monobore completions

• With the modular gun system, you are able to stack an optimum number of guns downhole for perforating the maximum interval.

• Several features make the modular gun system your best choice for perforating under a wide range of conditions.

– The guns are retrievable or can be left at the bottom of the hole.

– The system allows perforating in either underbalanced or overbalanced conditions over the entire interval.

– Wide range of gun sizes (2- to 7-in. OD) permits deployment over a wide range of casing, from 3 1/2 to 9 5/8 in.

• No rig is required—the system is ideal for rigless completions.

• The modular gun system can be deployed via coiled tubing, electric wireline, or slickline, as well as with conventional tubing or drillstring.

• The modular gun system allows a zone to be perforated and tested with no downhole restrictions below or above the packer.

• Proven VannSystem® guns and firing heads are used in the modular gun system.

Modular Gun System Configuration

*US Patent Number 5,366,014


The Modular Gun System Process

The modular gun system allows operators to deploy multiple gun sections to perforate long intervals. The gun modules are deployed downhole individually and stacked on each other at the perforating zone until the appropriate length is achieved with the lowermost gun module being supported by the gun hanger. This method avoids any gun length restrictions caused by the lubricator. The auto-release gun hanger positions the perforating assembly and allows it to remain adjacent to the desired interval. The guns are fired, via a pressure-actuated firing head, and are then, automatically released to the bottom of the hole where they can later be retrieved or left in the hole.

The modular gun system is ideal for use in wells with rathole length restrictions and rigless completions.

Rathole Length Restriction

In this application, insufficient rathole length causes the uppermost gun modules to remain adjacent to the perforated interval after they are fired—where they may interfere with production from the well. The modular gun system allows the guns to be retrieved in sections without having to kill the well.

Rigless Completion

On wells where the completions are installed with wireline or coiled tubing, the modular gun system is the preferred method for perforating. No rig is required, saving both time and money.

HAL

1545

8

Stinger Assembly

HAL

1545

7

Skirt Assembly


Auto-Release Gun Hanger

One of the main features of the modular gun system is the auto-release gun hanger. For high volume testing and production, the auto-release gun hanger allows a zone to be perforated and tested with virtually no downhole restrictions. The auto-release gun hanger is deployed and set at the desired perforating depth. The lowermost gun is then lowered in the well where it is supported by the gun hanger. The remaining guns are then lowered and stacked. The entire perforating assembly can be positioned and retained adjacent to the desired interval until the guns are fired. The assembly is then automatically released to the bottom of the well.

Benefits

• No tubing is required between the guns and the packer.

• No wireline is required to drop the assembly.

• Maximum desired underbalance or overbalance can be used.

• Additional perforations may be added through the tubing at a later date.

• Production tubing can be run and tested independently from other tools.

• The gun hanger and guns are run on a workstring, wireline, or slickline.

• In BigBore™ monobore completions, the production tubing and permanent packer are installed before running the monobore perforating assembly.

• Remedial work, such as setting bridge plugs, adding perforations, and running coiled tubing, can be performed without pulling production equipment.

• Lower gun firing pressures can be used since all production equipment is pressure tested prior to deploying guns in the well. There is no need to exceed previous test pressures.

Auto-Release Gun Hanger

Silicone FluidChamber

Slip Cone

Automatic-JMandrel

Primacord

Slip Assembly

Time-Delay FirerCrossover

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On-the-Job Performance

A customer wanted to perforate a 46-ft interval in a well in central Texas. Total depth was 14,500 ft and included a bottomhole temperature of 370°F and 10-lb brine fluid in the well. Pipe included 7 5/8-in. casing with 5-in. 23.2 lb/ft liner polished bore respectable at 12,000 ft. The top of the liner was isolated with 4-in. bore drillable packer set inside the 7 5/8-in. casing.

Perforating equipment consisted of 3 3/8-in. perforating guns, loaded 4 spf, with 32-gram PYX charges and 100-grain PYX aluminum clad prima cord.

This gun hanger was adapted for hostile environment use. Preparations included dressing the tool with PYX explosives and using water in place of silicone oil inside the hanger. The hanger was fitted with an auto-J-latch to allow setting and unsetting with the wireline. A 300-lb weight was installed on the bottom of the gun hanger to permit running on electric wireline.

The running tools were used to deploy the gun hanger and gun module. Crossover subs were used to adapt the running tool threads to the electric wireline.

The gun hanger was attached with a modular stinger onto the running tool, casing collar locator (CCL), and electric wireline and run into the well. After reaching the approximate setting depth, gun hanger position was verified by checking the casing collars with the CCL. The gun hanger was set by up and down movement of the wireline. A decrease in wireline weight at the surface verified that the hanger had set. Additional weight was then slacked off. This caused oil to meter through an orifice in the hydraulic running tool. Five minutes later the tool released from the gun hanger.

Next, a running tool was installed onto the gun module firing head handling stinger. The CCL and electric wireline were attached into the running tool, and the entire assembly was run into the well. The gun module assembly was lowered to the top of the gun hanger and the casing collars were again checked with the CCL to verify hanger position. Weight was slacked off to release the running tool. Decrease in weight at the surface verified that the running tool had separated from the gun module. The running tool was then pulled out of the well. The entire deployment, from the time the first running tool was lowered into the well until the last running tool was removed, took about 5 hours.

Five days later, Halliburton was called to the wellsite to fire the guns. Tubing was pressured to 7,000 psi and released back to zero. Approximately 4 minutes later, the detonation was both felt and heard at the wellhead, indicating that the guns had fired. The well immediately began unloading 10-lb brine. A weighted slickline run was made to verify that the gun module and auto-release gun hanger had dropped into the rathole. There were no problems encountered during the entire operation. The customer was very pleased with the efficiency of the operation and the performance of the Halliburton crew.

Wireline

CCL

RunningTool

Stinger

Ported Sub

Firing Head

3 3/8-in. Gun

CCL

Running Tool

Stinger Skirt

Stinger

Air Chamber

Auto ReleaseGun Hanger

Auto-J

Weight

Wireline

Run 1 Run 2

HAL

1546

1


Setting Tools for the Auto-Release Gun Hanger

Running and Retrieving Tools

The running and retrieving tools for the modular gun system and the auto-release gun hanger gives customers flexibility in the conveyance of these tools in the well. There are four basic running tools that have been run with these systems: explosive set, jar down, hydraulic, and rotational set. Most of the tools are for wireline and slickline deployment of the systems. The on/off tool requires rotation to operate and is limited to tubing conveyed applications. All of these tools are reusable with a minimal amount of redressing.

Application

The running and retrieving tools are used for setting gun hangers in position, running modules, and retrieving modules. The tools break down into four categories: explosive set, jar down and jar up, hydraulic, and rotational set. There are many tools that can be used with the modular system. This manual has been written for the tools specially designed for the modular gun system or those recognized as a usable tool.

• Explosive set

–Adapter kit for Baker #10 setting tool

–Adapter kit for Baker #20 setting tool

• Jar down

–Otis® SB and RB shear release and running tool

–Camco JDC and JUC

• Hydraulic

–Hydraulic JDC running and retrieving tool

• Rotational set

–Right hand release on/off tool

Running Tool Assembly Modular3.12 in. OD for Baker # 20 Setting Tool

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Detach™ Separating Gun Connector

The Detach™ separating gun connector allows operators to deploy long gun sections into the well. The guns are deployed downhole in a single trip and placed across the perforating zone supported by a gun hanger or plug. The guns are fired when desired and then, will automatically separate, which allows them to be retrieved in manageable sections or left in the hole. The Detach separating gun connector is ideal for use in monobore wells with rathole length restrictions and in rigless completions.

Rathole Length Restriction

In this application, insufficient rathole length causes the uppermost gun modules to remain adjacent to the perforated interval after they are fired where they may interfere with production from the well. With the Detach separating gun connector, gun sections can be removed from the perforated interval without having to kill the well.

Rigless Completion

On wells where the completions are installed with wireline or coiled tubing, the Detach separating gun connector or modular gun system is

the preferred method for perforating. No rig is required—saving both time and money.

Operation

When the firing head detonates the detonating cord initiator, the explosives train continues through the tool and detonates two shaped charges that punch holes in the vent sub. At this point, wellbore pressure is allowed to enter the assembly and move the mandrel lock piston upward, allowing the retaining dogs to move inward, releasing the stinger, and allowing the gun sections to separate.

Advantages

• Can deploy entire gun assembly to cover the zone of interest in a single trip and retrieve in manageable gun sections without killing the well

• Guns can be retrieved or left at bottom of the hole.

• Allows perforating in either underbalanced or overbalanced conditions over the entire interval

Detach™ Separating

Gun Connector

HAL

1207

0 HAL

1152

5

Detach™ Separating Gun Connector Specifications

SAP No.

Upper Thread Size and Typein. (mm)

Lower Thread Size and Type

in. (mm)

Maximum OD

in. (mm)Minimum

ID

Makeup Lengthft (m)


Tensile Ratinglb (kg)

Burst Pressure

Collapse Pressurepsi (bar)

101363724 2 3/8 (60.450)-6P Acme Pin

2 3/8 (60.450)-6P Acme Box

2.75 (69.850) N/A 2.86

(0.87)1,000 (69)

80,000 (36 300)* N/A 20,000

(1379)

101286871 2 7/8 (73.03)-6P Acme Box × Pin

2 7/8 (73.03)-6P Acme Box

3.38(85.85) N/A 2.74

(0.83)1,000(69)

110,000(49 800) N/A 20,000

(1379)

Temperature rating is determined by explosive.*Verification testing


G-Force® Precision Oriented Perforating System

Historically, oriented perforating was attempted via external orienting devices and weights (external to the gun and exposed to the casing environment). In the externally oriented systems, there is added friction created by the guns moving axially down the casing wall, which can significantly work against the orienting mechanism. In addition, doglegs and other discontinuities during the deployment can cause loss of orientation.

It was conceived that if the rotating device could be taken inside the protective environment of the carrier, adverse factors that can significantly decrease the ability to orient the guns in a desired direction could be overcome, if not completely eliminated.

Halliburton's G-Force® system is comprised of an internal orienting charge tube assembly and gun carrier, which allows perforating in any direction irrespective of the gun's position relative to the casing.


• Able to go through restrictions not possible with older systems

• Since the orienting mechanism of the internal orienting system is contained within the gun carrier, the fundamental orienting design is unaffected by potential restrictions in the completion string.

• Able to run through tubing and orient in casing

• No need for fin tandems, eccentric tandems, and swivel subs

• Increased orientation accuracy: the operating range will be for wells of 25° deviation and greater. For deviated wells, the accuracy range is ± 5°.

• Compatible with live well intervention systems such as the AutoLatch™ connector, ratchet connector, and the modular gun system

• Gun assemblies can be centralized in the casing.

• Can be deployed on coiled tubing, wireline, slickline, or jointed pipe

• No external weight bars required means no gaps between loaded sections and no lost shots.

G-Force® System

HA

L12019


3.375-in. G-Force® System Specifications

SAP No.


in. (mm)Gun ODin. (mm)

Lengthft (m)

Maximum Shot

DensityShot

PhasingPerforation

Planes

Vertical Shot

Spacingin. (mm)

Maximum Diameter after Detonation

in. (mm)

Distance from Top End of Gun to

First Shotin. (mm)

101300078 2 7/8 6P Acme (73.03 6P Acme)

3.375(85.73)

22(6.7)

4 spf (13 spm) 180° 2 2.8

(71.12)3.42

(86.87)8.50

(215.90)

SAP No.Tensile Load

lb (kg)


Tandem Tensile Loadlb (kg)

Survival Test Medium

101300078 238,000(107 954)

25,000(1725)

355,000(161 025) Fluid

4.625-in. G-Force® System Specifications

SAP No.


in. (mm)Gun ODin. (mm)

Lengthft (m)

Maximum Shot

DensityShot

PhasingPerforation

Planes

Vertical Shot

Spacingin. (mm)

Maximum Diameter after Detonation

in. (mm)

Distance from Top End of Gun to

First Shotin. (mm)

101305067 4.00 6P Acme (101.60 Acme)

4.625(117.48)

22(6.7)

4 spf (13 spm) 180° 2 2.8

(71.12)4.69

(118.87)8.50

(215.90)

SAP No.Tensile Load

lb (kg)


Tandem Tensile Loadlb (kg)

Survival Test Medium

101305067 403,000(182 783)

20,000(1378.95)

563,000(255 372) Fluid

G-Force® Charge Performance Data

Size SPF PhasingExplosive

Type Part No. Charge TypeExplosive

LoadCasing

SizeTarget

Strength EHDTotal Target Penetration

3 3/8 4 G-ForceHMX 101233817 Millennium™ 15 4 1/2 6000 0.26 24.07

HMX 101366678 Millennium 21 4 1/2 5671 0.39 32.57

4 5/8 4 G-Force

RDX 100005322 DP 32 7 5117 0.42 27.00

HMX 101210636 Millennium 39 7 5518 0.35 43.60

HNS 101210636 Millennium 39 7 7559 0.33 31.20

HNS 101287306 Millennium 39 7 5/8 6349 0.29 30.20


Explosive Transfer Swivel Sub

The explosive transfer swivel sub allows two sections of guns to rotate independently of one another. This independent rotation is important on long strings of guns in horizontal wells when they must be oriented in a specific direction. It is easier to orient several short sections of guns, rather than one long section.


• Useful in horizontal wells when shots need to be oriented in a specific direction to the wellbore

• Bidirectional, allowing firing from either direction

Operation

This swivel sub can be run as a connector between two guns to allow them to rotate independently without breaking the explosive train. In other words, this sub passes on the explosive transfer to the next gun.

Explosive Transfer

Swivel Sub Assembly

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13

Explosive Transfer Swivel Sub Specifications

SAP No.


in. (mm)

Maximum OD

in. (mm)

Makeup Lengthft (m)



Maximum Operating Tensile Load*

lb (kg)

101271529 2 3/8 (60.33) 6P Acme Box × Pin

2.75(69.85)

1.13(0.344)

20,000 (1379)

108,000(48 988)

32,000(14 515)

101271553 2 7/8 (73.03) 6P Acme Box × Pin

3.375 (85.73)

1.13(0.344)

20,000 (1379)

190,000(86 183)

40,000(18 144)

101271546 4.00 (101.60) 6P Acme Box × Pin

4.625(117.47)

1.16(0.353)

20,000(1379)

332,000(150 593)

60,000(27 216)

101284187 4.420 (112.27) 6P Acme Box × Pin

5.125(130.18)

1.13(0.344)

20,000 (1379)

416,000(188 694)

60,000(27 216)

101278821 5 1/8 (130.18) 6P Acme Box × Pin

5.750(146.05)

1.16(0.353)

20,000(1379)

410,000(185 973)

60,000(27 216)

*Maximum operating tensile load is the point at which the ball bearing race will start to deform, and the tool will not function as designed.Temperature rating is determined by explosive.


Eccentric Orienting Tandem

For several years, Halliburton successfully ran oriented perforating jobs using a fin welded to a gun connection every 30 ft in conjunction with swivel assemblies.

Now, a second method for orienting perforations referred to as eccentric subs has been developed. The eccentric sub is run in place of the finned tandem still in conjunction with a swivel assembly.

The eccentric tandem works on the same principle as the fins. As the guns are run into the well, and transition from a vertical to deviated position occurs, the natural tendency is for the fin to orient to the high side of the wellbore. The eccentric tandem works on the same principle. The eccentric tandems allows for a greater degree of accuracy with an overall smaller profile.

Features

Eccentric subs allow perforating guns to be oriented in situations where the fin system is not ideal due to restrictions in the casing, fishing concerns, welding concerns, etc. Several tests and wells have been perforated using this new technique in the North Sea area and the Gulf of Mexico.

• Built with an adjustable ring, which makes it possible to orient the shots in the casing to a predetermined direction

• Tensile strength of the eccentric sub equivalent to the standard gun connectors

• Available for most gun sizes

Benefits

• Eliminates the use of welded fins on the connectors

Eccentric Orienting Tandem

HAL

1545

6


Roller Tandem Assembly

Roller tandem assemblies are used to reduce the friction between the perforating guns and the casing. In some cases, the frictional drag can be reduced by as much as 90%.

Applications

• Running guns on coiled tubing in horizontal and highly deviated wells

• Dropping the guns into the rathole in highly deviated wells

• Can be deployed in conjunction with the modular gun system

Roller Tandem Assembly

HA

L10567

Roller Tandem Assembly Specifications

SAP No.Size

in. (mm)Effective OD

in. (mm) No. of RollersRoller

PhasingTensile Strength

lb (kg)Makeup Length

in. (mm)

120021632 2 3/4(69.85)

3.06(77.72)

6 (2 rows of 3) 60° 140,000

(63 503)6.97

(177.04)

100155770 3 3/8(85.72)

3.76(95.50)

8(2 rows of 4) 45° 246,000

(111 584)7.70

(195.58)

100155771 4 5/8(117.47)

5.63(143.00)

8(2 rows of 4) 45° 414,000

(187 787)9.25

(234.95)

101313551 7(177.80)

8.20(208.28)

8(2 rows of 4) 45° 444,000

(201 395)15.52

(394.21)


Centralizer Tandem

In certain types of TCP operations, it is desirable to centralize the guns and other tools in the casing. Halliburton has designed a full range of centralizers to meet this requirement for all gun sizes. The centralizers are designed to minimize the possibility of “hanging up” while running or pulling the guns, and to maximize the flow area around the centralizers.

Application

Two of the primary applications for the centralizers are:

1. When perforating with big hole charges, it is recommended to centralize the guns to ensure that the exit holes in the casing will all be of a consistent size. If the guns are not centralized, the size of the exit holes will vary according to the clearance from the gun to the casing. This can cause problems with sand control operations.

2. In modular gun completions, it is necessary to centralize the gun modules to obtain a reliable explosive transfer between modules.

Contact your Halliburton representative for a list of available centralizers.

Centralizer

Guns

Centralizer

Centralizer Tandem

HAL

1598

6


StimGun™ Assembly

The StimGun™ assembly is a process that combines perforating and perforation breakdown with propellant in a single tool and operation. The StimGun assembly has a propellant sleeve over a conventional Halliburton VannGun® perforating gun assembly. When the guns are detonated, the propellant sleeve is ignited, instantly producing a burst of high-pressure CO2 gas. This gas enters

the perforations, breaks through any damage around the perforation tunnel, and creates short fractures near the wellbore. As the gas pressure in the wellbore dissipates, the gas in the formation surges back into the wellbore carrying with it damaging fines. The StimGun assembly has been used with great success in conventional underbalanced perforating to obtain the benefits of both extreme overbalance from propellants and the surging effect from maximum underbalance.

Benefits

• Improved production or injectivity with greater uniformity in the perforation breakdown

• Improved connectivity to the undamaged reservoir matrix by extending fractures past damage induced by either drilling or completion practices

• Improved conventional underbalanced perforating by combining benefits of extreme overbalance in one operation

• Stimulation of near-wellbore on zones that cannot be treated conventionally with acid or hydraulic fracturing due to undesirable production from nearby gas cap or water contact

• Excellent pre-hydraulic fracture treatment assists in keeping perforations open and minimizes tortuosity effects, resulting in lower breakdown pressures and horsepower requirements on location.

Operation

The StimGun assembly consists of a cylindrical sleeve of gas-generating propellant-potassium perchlorate that slides in place over the outside of a conventional hollow steel carrier perforating gun. The StimGun assembly can be conveyed on either wireline, coiled tubing, or in a conventional perforation configuration. StimGun sleeves are similar to PVC pipe and must be protected and positioned on the gun with an oversized retaining collar that is secured to the gun scallop. Additional sleeve protection is achieved through centralization of the gun sections at the tandems.

StimGun is a trademark of Marathon Oil Company and is licensed to Halliburton by Marathon.

StimGun™ Assembly

RadioactiveMarker

Safety Joint

RetrievablePacker

Fill Disk

Firing Head

Centralizer

Fast GaugeRecorder

HAL

1541

7


StimGun™ Assembly Specifications

Gun Sizein. Sleeve SAP No.

Sleeve OD in. (mm)

Sleeve ID in. (mm)

Minimum Centralizer OD*

in. (mm)Propellant Mass**

lb/ft (kg/m)

2 1/2 58179 3.11 (78.99)

2.50 (63.50)

3.50 (88.90)

2.01 (2.99)

2 3/4 58190 3.36 (85.34)

2.75 (69.85)

3.76 (95.50)

2.01 (2.99)

3 1/8 58193 3.72 (94.48)

3.21 (81.53)

4.13 (104.90)

2.33 (3.46)

3 3/8 58195 4.02 (102.10)

3.38 (85.85)

4.40 (111.76)

2.67 (3.98)

4 58196 4.71 (119.63)

4.05 (102.87)

5.09 (129.28)

3.68 (5.47)

4 5/8 57514 5.21 (132.33)

4.72 (119.88)

5.63 (143.00)

3.33 (4.96)

5 1/8 101240496 5.81 (147.63)

5.175 (131.44)

6.18 (156.97)

3.99 (5.94)

5 3/4 215347 6.45 (163.83)

5.75 (146.05)

6.95 (176.53)

4.68 (6.97)

7 58159 7.88 (200.15)

7.09 (180.08)

8.25 (209.55)

7.01 (10.43)

StimGun sleeves are manufactured in standard 3 ft (0.91 m) lengths and are rated for a service temperature of 350°F (177°C). The sleeves are non-reactive to most commonly used oilfield fluids, including acids.*The StimGun sleeve is an oxidizer that is bonded with a resin or plastic, making it quite brittle; therefore, it is required that the perforating gun be centralized to this minimum OD to provide protection when the assembly is in the wellbore.**CO2 gas generated from a propellant burn is estimated at 7.06 scf per kg of material at standard conditions.

Retaining Collar Assembly Specifications

SAP No.Gun Size

in.OD

in. (mm)ID

in. (mm)Sleeve OD

in. (mm)

Minimum Centralizer OD

in. (mm)Flow Area through Collar

in.2 (mm2)

101233588 2 1/2 3.38 (85.85)

2.56 (65.02)

3.11 (78.99)

3.51 (89.15)

1.10 (709.67)

101233598 2 3/4 3.63 (92.20)

2.81 (71.37)

3.36 (85.34)

3.76 (95.50)

1.15 (741.93)

101233215 3 1/8 4.02 102.10)

3.18 (80.77)

3.72 (94.48)

4.13 (104.90)

1.21 (780.64)

101240387 3 3/8 12 spf 4.27 (108.45)

3.43 (87.12)

4.02 (102.10)

4.40 (111.76)

1.71 (1103.22)

101222271 3 3/8 4.27 (108.45)

3.43 (87.12)

4.02 (102.10)

4.40 (111.76)

1.71 (1103.22)

101233163 4 4.96 (125.98)

4.06 (103.12)

4.71 (119.63)

5.09 (129.28)

2.00 (1290.32)

101227396 4 5/8 5.50 (139.70)

4.69 (119.12)

5.21 (132.33)

5.63 (143.00)

2.00 (1290.32)

101239368 5 1/8 6.05 (153.67)

5.19 (131.82)

5.81 (147.32)

6.18 (156.97)

2.21 (1425.80)

101303748 5 3/4 6.70 (170.18)

5.82 (147.82)

6.45 (163.83)

6.95 (176.53)

2.70 (1741.93)

101292913 7 8.15 (207.01)

7.07 (179.57)

7.88(200.15)

8.25 (209.55)

3.75 (2419.35)



ly

StimTube™ Assembly

The StimTube™ assembly is a process that uses the same solid propellant technology employed by the StimGun™ assembly to stimulate existing perforations, slotted liners, or openhole sections when it is not desirable to add perforations. The StimTube assembly is a hollow rod with propellant molded onto it and standard detonating cord run through the ID of this rod to provide the ignition system. When the detonating cord is ignited, the solid propellant breaks up into many smaller pieces, allowing it to burn very rapidly and producing CO2 gas. This gas enters the perforations, breaking through any damage around the perforation tunnel, creating short fractures near the wellbore. As the gas pressure in the wellbore dissipates, the gas in the formation surges back into the wellbore, carrying with it damaging fines. StimTube assembly jobs are designed using Halliburton’s PulsFrac™ simulator, which assists in achieving consistent results without compromising safety or wellbore integrity.

Operation

The StimTube assembly consists of a solid stick of gas-generating propellant-potassium perchlorate that is molded onto a hollow rod with detonating cord run through the inside of this rod. The StimTube assembly can be conveyed on either wireline, coiled tubing, or threaded pipe. Standard perforating safety, arming, and firing procedures are used. The StimTube assembly is available in a wide range of sizes (1 1/2 to 3 in.) and lengths to accommodate most commonly used completion configurations. The industry standard detonating cord provides consistent,

reliable, and instantaneous ignition over the entire length of the StimTube assembly.

When deployed on coiled tubing or threaded pipe, the StimTube assembly is run inside a vented hollow steel carrier.

Benefits

• Improved production or injectivity with greater uniformity in the perforation breakdown

• Improved connectivity to the undamaged reservoir matrix by extending fractures past damage induced by either drilling or completion practices

• Stimulation of near-wellbore on zones that cannot be treated conventionally with acid or hydraulic fracturing due to undesirable production from nearby gas cap or water contact

• Excellent pre-hydraulic fracture treatment assists in keeping perforations open and minimizes tortuosity effects resulting in lower breakdown pressures and horsepower requirements on location.

• Selective stimulation of long openhole horizontal sections

StimTube and StimGun are trademarks of Marathon Oil Company and are licensed to Halliburton by Marathon.PulsFrac is a trademark of John F. Schatz Research and Consulting, Inc.

StimTube™ Assembly

RadioactiveCollar

On/Off Connector

PLS Packer

Vent

Firing Head

StimTube™ Assemb

Fast GaugeRecorder

HA

L11

84

2



StimTube™ Assembly Specifications

Tool Sizein.

Minimum Centralizer OD*in. (mm)

Propellant Mass lb/ft (kg/m)**

1 1/2 1.63 (41.40)

0.66 (0.98)

1 11/16 1.94 (49.27)

0.97 (1.44)

2 2.25 (57.15)

1.70 (2.53)

2 1/2 2.63 (66.80)

2.76 (4.10)

3 3.25 (82.55)

4.19 (6.23)

StimTube™ assemblies are manufactured in lengths from 1- to 5-ft (0.30 to 1.52 m) sections that can be connected with collars for required job parameters. The propellant is rated for a service temperature of 350°F (177°C) and is non-reactive to most commonly used oilfield fluids including acids.*The StimTube assembly is an oxidizer that is bonded with a resin or plastic, making it quite brittle; therefore, it is required that the assembly be centralized to this minimum OD to provide protection when the assembly is conveyed in the wellbore on wireline.**CO2 gas generated from a propellant burn is estimated at 7.06 scf per kg of material at standard conditions.These ratings are guidelines only. For more information, consult your local Halliburton representative.


PerfStim™ Process

The PerfStim™ process uses an extreme overbalanced condition to simultaneously perforate and stimulate a well. The process not only produces cleaner perforations in low-pressure formations, it also initiates fractures in the formation, reducing stimulation costs.

Benefits

• Gets production flowing quickly

• Saves rig time

• Helps develop negative skin factors

• Gives an early evaluation of a well’s potential

• Uses less horsepower than full scale stimulations

Operation

In the PerfStim process, an extreme overbalanced condition is created—pressure gradients of at least 1.4 psi/ft (31 bar/m).

When the perforating gun fires, the pressure drives a fluid “spear” into the perforation at velocities exceeding 3,000 ft/sec (900 m/sec) and at rates that can exceed 140 bbl/min. Crushed zone damage is removed and small fractures are created—improving initial production and treatment results.

The PerfStim process is licensed to Halliburton by Oryx Energy Company.PerfStim is a trademark of Oryx Energy Company.

Packer

Firing Head

VannGunAssembly

®

HA

L1

53

87

Halliburton’s VannSystem® toolstring is used in typical PerfStim™ procedures. The tubing conveyed system helps to allow for the highest possible bottomhole pressures. A small volume (usually no more than a 300-ft column) of non-damaging fluid is placed above the gun, then pressured with nitrogen. If needed, a liquid can be bullheaded on top of the nitrogen column. The VannGun® perforating assembly can remain attached to the toolstring or dropped into the rathole after the guns have been fired.


POWR*PERFSM Perforation/Stimulation Process

POWR*PERFSM perforation/stimulation process is a completion process that uses proven extreme overbalance perforating techniques. This method is coupled with the release of an erosive agent at the moment of VannGun® detonation to clean and scour near-wellbore damage and enhance conductivity of fractures created by extreme overbalance perforating.


• Overcomes skin damage in low pressure, high permeability wells

• Can be a useful pre-frac evaluation tool

• Applicable to both new wells and wells with nearby water or gas

• Compatible with all casing sizes and tubulars

Operation

The POWR*PERF tool is run as a normal part of the completion

assembly. A non-damaging fluid is added to the tubing to serve as a medium for carrying the bauxite into the formation. After the assembly has been positioned across the producing zone, the tubing is energized with nitrogen gas to create a pressure gradient of no less than 1.4 psi/ft (31 bar/m). A model KV-II firing head, which has been pre-set to function at the desired bottomhole pressure, detonates the VannGun assembly and opens flow ports to allow the fluid and nitrogen to rush toward the formation. The fluid “spear” is driven ahead of the expanding nitrogen gas into the formation at velocities that can exceed 140 bbl/min. The bauxite material is ejected into the fluid stream at the moment of detonation by specially designed shaped charges. The combination of fluid and bauxite serves to fracture, erode, and scour all of the perforations, and to further enhance the fractures created by extreme overbalance perforating.

POWR*PERF is a service mark/trademark of Marathon Oil Company and licensed by Halliburton.

POWR*PERFSM Perforation/Stimulation Process

RetrievablePacker

KV-II FiringHead

ProppantCarrier

VannGunAssembly

®

HA

L1

53

14

POWR*PERFSM Perforation/Stimulation Process Specifications

POWR*PERF Carrier Sizes

in. (mm)

Available Lengths

ft (m)

Bauxite Capacities

lb (kg)

AssemblyWeight lb (kg)


Minimum Ratio Interval to

POWR*PERF Carrier

3 1/8 (79)

16 (4.88) 56 (25.40) 250 (113.40) 20,000 (1379) 1:1

22 (6.71) 80 (36.29) 344 (156.04)

3 3/8 (86)

16 (4.88) 67 (30.39) 323 (146.51) 25,000 (1724) 1:1

22 (6.71) 95 (43.09) 447 (202.76)

4 (102)

16 (4.88) 95 (43.09) 407 (184.61) 19,000 (1310) 1:1

22 (6.71) 170 (77.11) 599 (271.70)

4 1/2 (114)

16 (4.88) 140 (63.50) 492 (223.17) 18,000 (1241) 1:1

22 (6.71) 200 (90.72) 684 (310.26)

Maximum operating pressure is determined by tubulars. These ratings are guidelines only. For more information, consult your local Halliburton representative.


Quick Torque™ Connector

The Quick Torque™ connector consists of connectors that cover both ends of each gun section to enclose the assembly. The connectors have a common, self-aligning drillpipe thread that allows automatic or manual make-up. Explosive transfer occurs through a web, making the system self-contained for added safety. With these connectors, TCP gun assemblies can now be picked up by the rig equipment and properly made up using iron roughneck equipment, without the need for human intervention. It simplifies the process and saves time by eliminating assembly of the components on the rig.


• Standard NC38 thread make-up procedure

• Redressable

• Self-contained system increases personnel safety on the rig floor—no human intervention is needed

• Once the thread protectors are removed, all subsequent steps can be automated

• Efficient, automated system saves rig time

• Allows venting of any built-up pressure during shipping

• No exposed explosives

• Q125 material, sour service > 175° F

Operation

This system can be used on any rig with automatic or manual pipe handling equipment. It can be used with 4 5/8-in. standard or 4 5/8-in. self-orienting TCP gun systems, and a 3 3/8-in.-OD or smaller firing head.

HA

L1

43

99

HA

L1

43

98

Gun Sub-Assembly

Firing Head Sub-Assembly


Quick Torque™ Connector

SAP No.Thread

ConnectionTool Max. OD

in (mm)

Maximum Operating

Pressure* psi (bar)

Temperature Rating*°F (°C)

Makeup Length

in. (mm) End ConnectionsTensile Rating

lb (kg)

101351984Pin Connector

Assy, NC38 Pin x Acme Pin

4.75(120.65) 20,000 (1379)

Determined by explosives and

elastomers

6.75 (.17)

4-6 Acme Pin x Modified NC38 Pin

493,500 (223,848) Limited by 4 -6 Acme Pin Thd

101352042

Firing Head Connector Assy,

NC38 Pin x Double Acme

Pin

4.75 (120.65) 20,000 (1379)


elastomers

7.61 (.19)

2 7/8-6 Acme and Pin x 4-6 Acme Pin x Modified NC38 Pin

493,500 (223,848)

Limited by 4 -6 Acme Pin Thd

101351885Box Connector

Assy, NC38 Box x Acme Pin

4.75 (120.65) 20,000 (1379)


elastomers

23.08 (.59)

Modified NC38 Box x 4-6 Acme Pin

493,500 (223,848)

Limited by 4 -6 Acme Pin Thd

101354907

Crossover, Standard NC38 Box x Modified

NC38 Pin

4.75 (120.65) 20,000 (1379)


elastomers

13.56 (.34)

NC38 Box x Modified NC38 Pin

398,000 (180,530)

Limited by NC38 Box

101381170

Firing Head Connector Assy, Firing Head on Bottom, NC38 Box x Double

Acme Pin

4.75 (120.65) 20,000 (1379)


elastomers

23.08 (.59)

Modified NC38 Box x 4-6 Acme Pin x

2 7/8-6 Acme Pin

493,500 (223,848)

Limited by 4-6 Acme Pin Thd

* Maximum Operating Pressure and Temperature Rating based on the elastomers.


Pump-Through Firing Head

The 1 11/16-in. pump-through firing head is designed to be run on coiled tubing and is used for breaking the ceramic flapper valve disk on a one-trip coiled tubing operation. The firing head originates from proven technology in the 1 11/16-in. pressure actuated pressure firing head. The components were hardened to withstand pumping erosion, and an outer tube is incorporated to allow fluid circulation to the bottom of the tool. A miniature shaped charge is set in the bottom of the firing head to shoot into the ceramic disk. The assembly is actuated by dropping a ball through the coiled tubing, which seats in the assembly to allow a pressure differential to actuate the firing head and shape charge.

Application

The pump-through firing head can be used to circulate debris off of a barrier, such as a ceramic disk, and then shoot into the barrier to break it up. This function is primarily developed toward circulating sand and other debris off of a ceramic disk in a production well, and then shooting into the disk to allow access below.

Firing Head Assembly 1 11/16-in. Pump Through

HA

L15777

Pump-Through Firing Head Specifications


in. (mm)Maximum OD

in. (mm)Minimum ID*

in. (mm)


Flow Area (before firing)

in.2 (mm2)Temperature

Rating

Axial Load Ratinglb (kg)


Overall Length

in. (mm)Masslb (kg)

Maximum Flow Rate

bbl/min (m3/min)

1.315 NU-10RD Pin

(33.40 NU-10RD Pin)

2.3(58.42)

0. 44 (11.18)

3,000 ± 10% at 70°F(207)

0.15(96.77)

As perexplosives

54,400(24,700)

23,200(1600)

22.69(576.32)

16.9(7.68)

2.5(0.397)

*Through ball seatMinimum Operating Pressure is not applicable.Burst Pressure is not applicable.

An

cillary Equ

ipmen

t

Ancillary Equipment

Automatic-Release Gun Hanger (page 4)

Automatic-release gun hangers (ARGH) allow perforating and testing of a zone without downhole restrictions. The perforating assembly can be positioned and retained adjacent to the desired interval. The drillpipe or tubing is then removed. Once surface equipment is installed, guns are automatically detonated and released in the bottom of the well.

Emergency Release Assembly (page 8)

The emergency release assembly is designed to run in conjunction with the ARGH. The emergency release is run between the gun hanger and guns to serve as a “weak point” in case the hanger gets stuck while running in hole.

Y-Block Assembly (page 9)

The Y-block assembly is used in dual and single selective completions to attach or hang guns from the long string. These assemblies are custom-made according to casing ID, tubing size and type, and gun size.

Fast Gauge Recorder (page 10)

The fast gauge recorder is a downhole gauge that records important pressure and temperature data in high-pressure, severe shock/vibration environments. The pressure profile collected is used for two important objectives. The first is to verify proper propellant burn as well as determine the fracturing response of the formation by analyzing post-job data with the pre-job model done with the PulsFrac™ modeling software. The second objective is to provide important information, relative to the perforating event, for the engineering and design of downhole tools.

Balanced Isolation Tool (page 12)

The ported balanced isolation tool (BIT) assembly is used in situations when venting devices cannot be utilized because of packer selection or well conditions. Ported BIT assemblies replace the fill disk assembly and are used in place of a perforated sub. The BIT helps prevent contamination of the fluid below it from the fluid above it through the glass disk, which helps prevent debris from setting on the firing head. Pressure is balanced across the glass barrier through equalizing ports in the piston.

Annular Pressure-Control Line Vent (page 14)

Annular pressure control line (APF-C) vent devices isolate the tubing from annulus fluid or pressure. The vent is actuated by rathole pressure after the perforating assembly is detonated and then provides a flowpath for the formation fluid into the tubing string.

Annular Pressure-Control Line Swivel Sub (page 15)

When run in conjunction with the annular pressure control line (APF-C) firing head, the APF-C swivel sub provides a swivel point between the guns and packer when it is desired to have the guns rotate freely as when orienting shots in a deviated well.

Annular Pressure-Control Line Tubing Release Assembly (page 16)

The 2 7/8-in. APF-C tubing release assembly (APF-C TR) provides a mechanical method of releasing the APF-C firing head and VannGun® assembly from the tubing string.

PulsFrac is a trademark of John F. Schatz Research and Consulting, Inc.

Ancillary Equipment 7-1

Bar Pressure Vent (page 17)

The bar pressure vent is an internal sliding sleeve tool actuated by pressure in the tubing and run between the packer and the guns. It is designed to achieve a differential pressure between the formation and the tubing string. The tool helps to safely allow differential pressure in wells with existing open perforations or in unperforated wells.

Below-Packer Vent Device (page 18)

The below-packer vent device (BPVD) was developed for use with the annulus pressure crossover assembly (APCA). Surface pressure applied to the annulus is transmitted through the APCA to a closed chamber below the vent device and above a pressure-responsive firing head. The vent can be set to work before or after the perforating assembly is detonated.

Maximum Differential Bar Vent (page 19)

The maximum differential bar vent (MDBV) is a vent run between the perforating guns and packer. After the packer is set, the vent opening creates communication between the tubing and rathole. The vent is opened by breaking the plug inside the tool and allowing the sleeve to uncover the ports. Running the vent allows for running of the tubing in the well with no hydrostatic pressure in the tubing.

Pressure-Operated Vent (page 20)

The pressure-operated vent (POV) design helps achieve a differential pressure between the formation and tubing string and provides a way to open the vent and test the packer before guns are fired. When guns are positioned and the packer set, the predetermined amount of fluid is added to the tubing. Adding the fluid into the tubing causes the vent to open and helps create proper pressure differential before firing.

Vann™ Circulating Valve (page 21)

The Vann™ circulating valve (VCV) can be used as a circulating valve for displacing well fluids before setting a packer. After fluid is displaced, pressure to the tubing or annulus to rupture a disk and close the valve.

Automatic Release (page 22)

The automatic release (AR) allows perforating guns to immediately drop after firing.

Mechanical Tubing Release (page 24)

The mechanical tubing release (MTR) provides the option of keeping or releasing the VannGun® assembly from the tubing string. The MTR is usually run above the firing head and below the production ports below the packer. The MTR mechanism is operated by a standard shifting tool.

7-2 Ancillary Equipment

Pressure-Actuated Tubing Release (page 26)

When mechanical or slickline devices are not desirable, the pressure-actuated tubing release (PATR) is used to separate the guns from the toolstring. The guns drop off of the production tubing when separated. Once the guns drop away, other tools and operations have no restrictions through the end of the tubing. The housing attached to the string has a greater ID than the tubing.

DPU® Downhole Power Unit (page 27)

The DPU® downhole power unit is an electromechanical device that is designed to produce a linear force for setting (or pulling) wellbore tools such as Monolock® locks, bridge plugs, or packers. The slickline version of the DPU unit uses batteries to provide the energy to the motor and timing circuits. An electric-line version without the timer, circuits, and batteries is also available. A modified version is used to fire perforating guns using a model III-D firing head.

SmartETD® Advanced Electronic Triggering Device (page 28)

The SmartETD® tool is an advanced electronic triggering device that provides an accurate, safe, and reliable method to run and fire downhole explosive tools using slickline. With its built-in sensor and memory capabilities, it can record and store downhole temperature and pressure data that can be used by the slickline specialists to program firing parameters.

Coiled Tubing Conveyed Perforating (page 29)

Conveying perforating guns to the zone of interest with coiled tubing has been effectively used for many years since faster run-in times occur when compared to conventional methods. Also, the guns can be detonated either with wireline or a pressure-activated firing head.

Fill Disk Assembly (page 30)

The fill disk assembly (FDA) is used in place of a perforated sub and replaces the balanced isolation tool in wells with reasonably clean fluids. The glass disk helps prevent debris from settling on the firing head, while pressure is equalized across the glass disk. The FDA is run between the firing head and packer.

Gun Guides (page 31)The gun guides are used with Y-blocks in dual- and single-string completions. In a dual completion, gun guides help maintain proper orientation of guns attached to the short string.

EZ Pass™ Gun Hanger (page 32)

The EZ Pass™ gun hanger runs with Halliburton’s modular gun system. The advanced design includes slips that remain retracted within slip housing until the tool is set. After the perforating event, slips return to the running position and the tool auto-releases. If desired, the hanger can be fished with a standard pulling tool and retrieved from the well.

Hydraulic Metering Release Tool for the Single Trip System (STPP™-GH) (page 34)

The hydraulic metering release tool is one component of the single trip system that allows us to perforate and frac-pack a zone of interest in a single trip.


Automatic-Release Gun Hanger—Rotational Set



With the ARGH:

• No tubing is required between the guns and packer.

• No wireline work is required to drop the assembly.

• No restrictions are left in the casing below the packer.

• The maximum desired underbalanced pressure can be used.


• The ARGH and guns are run on the workstring.

• The risk of presetting the packer is reduced.

• In BigBore™ monobore completions, the production tubing and permanent packer are installed before running the ARGH perforating assembly.

• Remedial work can be performed without pulling production equipment (such as setting bridge plugs, adding perforations, running coiled tubing, etc.).

• Lower gun-firing pressures can be used since all production equipment is pressure-tested before the guns are installed in the well (no need to exceed previous test pressures).

Operation

The ARGH is made up on the bottom of the perforating assembly. A right-hand release on/off tool is made up on the top of the bottomhole assembly (BHA). After the BHA is correlated on depth, the operator picks up the string, turns it to the right, and slacks off weight on the ARGH. The ARGH should be set at this point.

With weight still on the BHA, the operator continues to turn the workstring to the right to release the on/off tool.

As the guns are detonated, the explosive train is continued to the ARGH. Two shaped charges are detonated into a sealed fluid chamber. This action eliminates the support to the slip assembly. The ARGH and perforating assembly are then released automatically and fall to the bottom.

Auto-Release Gun HangerRotational Set

Primacord

ShapedCharges

SiliconeFluidChamber

SlipAssembly

HA

L1

05

16


Automatic-Release Gun Hanger—Rotational Set Specifications

Casing ODin. (mm)

Casing Rangelb/ft (kg/m)

Maximum ODin. (mm)

Lengthft (m)

Minimum Tensile Rating lb (kg)

Minimum BHA Weightlb (kg)

Maximum Gun Weightlb (kg)

3 1/2(88.9)

5.7-10.2 (8.48-15.18)

2.75(69.85)

3.33(1.02)

25,000(11 300)

150(68)

12,300(5580)

4 1/2(114.3)

9.5-13.5(14.14-20.09) 3.75

(95.25)4.88

(1.49)85,000

(38 500)300

(136)40,000

(18 140)5(127)

11.5-18 (17.11-26.78)

5 1/2(139.7)

13-26(19.34-38.69)

4.5(114.3)

5.92(1.80)

120,000(54 400)

500(227)

40,000(18 140)

7(177.8)

17-38 (25.3-56.54) 5.5

(123.2)6.04

(1.84)120,000(54 400)

600(272)

40,000(18 140)7 5/8

(193.7)20-39

(29.76-58.03)

9 5/8(244.5)

29.3-53.5 (43.6-79.61)

8.0(203.2)

7.08(2.16)

120,000(54 400)

600(272)

40,000(18 140)


Automatic-Release Gun Hanger—Automatic-J Mandrel



With the ARGH:

• No tubing is required between the guns and packer.

• No wireline work is required to drop the assembly.

• No restrictions are left in the casing below the packer.

• The maximum desired underbalanced pressure can be used.


• The automatic-J ARGH and guns are run on wireline, slickline, coiled tubing, or the workstring.

• In BigBore™ monobore completions, the production tubing and permanent packer are installed before running the ARGH perforating assembly.

• Remedial work can be performed without pulling production equipment (such as setting bridge plugs, adding perforations, running coiled tubing, etc.).

• Lower gun-firing pressures can be used since all production equipment is pressure-tested before the guns are installed in the well (no need to exceed previous test pressures).

Operation

The automatic-J mandrel can be run on wireline, slickline, coiled tubing, or the workstring. Rotation is not required to set the automatic-J gun hanger. Upward and downward manipulation either sets or un-sets the hanger. As the guns are detonated, the explosive train is continued to the ARGH. Two shaped charges are detonated into a sealed fluid chamber. This action eliminates the support to the slip assembly. The ARGH and perforating assembly are then released automatically and fall to the bottom.

Automatic-Release Gun Hanger (ARGH) Automatic-J Mandrel

Silicone FluidChamber

Slip Cone

Automatic-JMandrel

Primacord

Slip Assembly

Time-Delay FirerCrossover

HA

L1

05

42


Automatic-J Mandrel Specifications

Casing ODin. (mm)

Casing Range

lb/ft (kg/m)

Maximum OD

in. (mm)Lengthft (m)

Maximum Operating Pressure*psi (bars)


Minimum BHA Weight

lb (kg)

MaximumGun Weight

lb (kg)

2 7/8(73.1)

6.4-6.50(9.52-9.67)

2.25 (57.2)

4.49-4.87(1.349-1.47)

20,000(1379)

25,000(11 300)

150(68)

9,000(4050)

3 1/2(88.9)

3 1/25.75-10.2

(8.56-15.18)

2.75(73.0)

4.87-5.28(1.47-1.59) N/A 25,000

(11 300)150(68)

12,300(5580)

4(101.6)

414.40

(21.43)

2.75(73.0)

4.87-5.28(1.47-1.59) N/A 25,000

(11 300)150(68)

12,300(5580)

3 1/2(88.9)

Slimhole

9.2-12.95(13.69-19.27)

2.50(63.5)

53.79-58.47(16.40-17.82)

20,000(1379)

25,000(11 340)

150(68)

20,000(9072)

4 1/2 (114.3)

4 1/29.5-13.5

(14.14-20.09)

3.75 (95.25)

7.95-9.28(2.40-2.80)

20,000(1379)

85,000(38 500)

300(136)

40,000(18 140)

5 (127)

515.0-18.0

(22.32-26.78)

3.75 (95.25)

7.95-9.28(2.40-2.80)

20,000(1379)

85,000(38 500)

300(136)

40,000(18 140)

4 1/2(114.3)

Slimhole

15.1-16.9(22.46-25.15)

3.50(88.9)

58.34-67.29(17.78-20.51) N/A 25,000

(11,340)200(91)

20,000(9072)

5 1/2(139.7)

15.50-23(23.06-34.22)

4.50(114.3)

9.31-10.29(2.80-3.10) N/A 120,000

(54 400)500

(227)40,000

(18 140)

7(177.8)

720-38

(29.76-56.54)

5.5 (123.2)

9.26-10.44(2.79-3.14) N/A 120,000

(54 400)600

(272)40,000

(18 140)

7 5/8(193.7)

7 5/824-39

(35.71-58.03)

5.5 (123.2)

9.26-10.44(2.79-3.14) N/A 120,000

(54 400)600

(272)40,000

(18 140)

9 5/8(244.5)

29.3-53.5(43.6-79.61)

8.0(203.2)

7.08(2.16) N/A 120,000

(54 400)600

(272)40,000

(18 140)

*As total gun weight increases, the maximum operating pressure decreases.Temperature rating is determined by explosives.These ratings are guidelines only. For more information, consult your local Halliburton representative.


Emergency Release Assembly

The emergency release assembly was designed to run in conjunction with the automatic-release gun hanger assembly. When deploying the gun hanger on tubing or drill pipe, the emergency release is run between the gun hanger and guns to serve as a weak point in case the hanger gets stuck while running in the hole. Pulling or jarring on the pipe will cause the emergency release assembly to shear, allowing the retrieval of the guns and tubing from the well.

When deploying the gun hanger on wireline, the rope socket typically acts as the weak point.

Emergency Release Assembly

HAL

1598

7

Emergency Release Assembly Specifications

SAP No.OD Sizein. (mm) No. Shear Screws Temperature Rating

Pressure Ratingpsi (bar)

101201127 3 3/8 (85.73)

8 steel shear screws rated at 5,600 lb per screw Determined by explosives 25,000

(1724)


Y-Block Assembly

The Y-block assembly is used in dual completions and single selective completions to attach or hang guns from the long string.

In single selective completions, this installation is run either for selectively shooting and testing two zones or for production when the application requires the option of producing two zones separately through one tubing string.

In dual completions, the assembly allows for the elimination of the tail pipe between the dual packer and the gun.

The Y-block assembly is available as a ported or non-ported assembly. The ported Y-block allows guns to be fired upon applying pressure to the long string. In the non-ported assembly, there is no communication between the long string and the short string.

Y-Block Assembly

HA

L10578

Y-block assemblies are custom-made according to the casing ID, the tubing size and type, and the gun size. Consult your local Halliburton representative for ordering information.

Non-Ported Ported

RetrievablePacker

Sliding-Side Door®

Y-Block

VannGunAssembly

®

Time-Delay Firer

HydraulicPacker

Nipple

Vent

Tubing Release

Mechanical FiringHead

VannGunAssembly

Time-Delay FirerHAL

8139


Fast Gauge Recorder

The fast gauge recorder is a downhole gauge that records important pressure and temperature data in high-pressure, severe shock/vibration environments.

This gauge is typically used with StimGun™ assemblies or StimTube™ tools. The pressure profile collected is used to verify proper propellant burn as well as determine the fracturing response of the formation by analyzing post-job data with PulsFrac™ software.

The data the fast gauge recorder collects can be used to determine whether or not the job was executed properly, to validate computer models, and to make initial determinations of rock properties. The data can also be used to estimate fracture gradients.

The fast gauge recorder can perform within the rigors of perforating applications by withstanding shock loads of 100,000 g. The tool collects and records 115,000 data points per second to give exceptionally accurate and reliable information.

The programmable multi-speed feature allows flexibility in collecting pressure, acceleration, and vibration data at various sampling speeds and time intervals. The gauge starts sampling at a slow speed and when a pressure pulse or acceleration/vibration event occurs, the gauge automatically switches to a high sampling speed, then back to an intermediate speed, and finally back to a slow sampling speed. The process can be repeated until the memory is full.

Each gauge includes a shock mitigator which isolates the gauge from the tool, reducing shock and vibration (up to a factor of 10) that occurs when the gun ignites. Use of the shock mitigator lengthens the life of the recorder, battery, and sensors.

A special application of the 1 11/16-in. (42.86 mm) OD gauge is its use as a “drop bar” to fire a propellant or perforating gun. The gauge can be used with firing pin and fishneck attachments as the drop bar to trigger a gun firing head. It can be left there as long as necessary to collect pressure flow data. With this feature, the customer can retrieve pressure data from the gun and also determine if the gun actually fired.

Fast Gauge

Recorder

StimTube and StimGun are trademarks of Marathon Oil Company.PulsFrac is a trademark of John F. Schatz Research and Consulting, Inc.

HAL

1546

4

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Features

• Shock-hardened design

• High sampling speed

• Records pressure, acceleration, vibration, and temperature

• Programmable low, intermediate, and high speeds and time intervals

• Can be used as drop bar pressure gauge

Benefits

Fast Gauge Recorder Specifications

• Computer programming and data readout

• Internal microprocessor control

• Automatic sensor testing and balancing

• Selectable pressure, temperature, and acceleration/vibration ranges

• Measures tool movement and acceleration/vibration up to ±50,000 g

• Current and internal/battery voltage readouts to verify proper gauge operation

• Internal temperature and battery data

• Selectable sampling rates up to 115,000 data points per second

• Auto stop/start recording modes

• Includes shock mitigator

• Up to 1,048,756 data points of memory

• Uses low-cost standard AA alkaline or lithium batteries

Gauge Dimensions

Maximum Acceleration and Vibration Current Drain

Computer/Communications Software

Sensor Frequency Response Power Requirements

1 11/16 in. OD × 50 in. (22 lb) ± 50,000 g 500 uA sleeping

100 mA sampling750 MHz or greater PC, with standard RS-232 Windows 98* 0 to 10,000 Hz 6 to 12 volts, AA

alkaline or lithium cells

*Windows 2000 or NT is recommended.

Sampling RateTemperature Range

°F (°C)Pressure Range

psi (bar) Data Resolution Memory Capacity

115,000 points/seconddown to one sample every

10 seconds

-40 to 248(-40 to 120)

35,000 (2413) peak 15,000 (1034) continuous

12 bits @ 115,000 data points/second 1,048,576 data points



The balanced isolation tool (BIT) assembly is used where either packer selection or well conditions preclude the use of a venting device. The BIT assembly replaces the fill disk assembly and is used in place of a perforated sub. The BIT helps prevent contamination of the fluid below it from the fluid above it. Debris or solids in the fluid above should not pass through the glass disk that is in the floating piston. The glass disk helps prevent debris from setting on the firing head. Pressure is balanced across the glass barrier through equalizing ports in the piston.

The BIT assembly is run between the firing head and packer. The recommended minimum distance from the BIT to the firing head is 30 ft (9.14 m).


• Allows mud and debris to be circulated off the glass barrier through the flow ports above the glass barrier

• Allows displacement of the tubing with a lighter fluid or nitrogen before firing the guns

• Allows swabbing of the tubing to achieve differential pressure

• Allows stopping and circulating at any depth since flow ports are always open

• Can be run with either a mechanical or pressure-actuated firing head

Operation

The basic components of the BIT are a floating piston with a glass disk, a ported lower housing, and a top housing. The BIT is run with clean fluid below it.

The upward travel of the floating piston is limited by the bottom of the top sub. A pressure increase above the glass barrier causes the piston to move down and forces fluid below the glass barrier out of the bleeder ports. A pressure increase below the glass barrier forces the piston to move up or forces fluid out of the bleeder ports.

The piston moves up or down within its limits to help prevent the glass barrier from breaking. The glass barrier remains intact until the bar passes through it. As fluid enters or leaves the tubing through the ports, debris on the glass barrier is washed off.


(BIT)

HAL

1546

0


Balanced Isolation Tool (BIT) Specifications

SAP No.


Maximum ODin. (mm)

Minimum ID in. (mm)

No. of Ports

Total Flow Area

in.2 (cm2)



120022203 1.90 (48.26) EUE 10 Rd Box × Pin

2.50 (63.50)

1.61 (40.89) 4 2.03

(13.10)2.09

(0.64)110,000(49 800)

101318220 2 3/8 (60.33) EUE 8 Rd Box × Pin

2.895(73.4)

2.0 (50.80) 4 3.09

(19.96)2.02

(0.62)100,000(45 300)

100014322 2 3/8 (60.33) EUE8 Rd Box × Pin

3.10(78.74)

2.0 (50.80) 4 3.14

(20.27)2.15

(0.65)155,000(70 200)

100014323 2 7/8 (73.03) EUE 8 Rd Box × Pin

3.75 (95.25)

2.44 (61.98) 4 4.68

(30.19)2.41

(0.73)200,000(90 700)

100156936 3 1/2 (88.90) EUE 8 Rd Box × Pin

4.25(107.95)

3.0(76.20) 4 7.07

(45.60)2.41

(0.73)280,000

(126 000)



Annular Pressure-Control Line Vent

The annular pressure-control line (APF-C) vent is a device that isolates the tubing from annulus fluid or pressure. The vent is actuated by rathole pressure after the perforating assembly has been detonated. It then provides a flowpath for the formation fluid into the tubing string.


• Ideal for highly deviated or horizontal wells

• Requires minimal pressure to operate

• Eliminates nitrogen displacement or swabbing the tubing string to achieve desired underbalance

Operation

The APF-C vent is run directly on top of the APF-C firing head. When the perforating assembly is detonated, gun pressure shifts an actuating piston into a power piston. This shift opens the flow ports to the tubing.

Annular Pressure-Control Line (APF-C) Vent

HAL

1544

1

Annular Pressure-Control Line (APF-C) Vent Specifications

SAP No.


in. (mm)

Maximum OD

in. (mm)

Minimum ID

in. (mm)

No. and ID of Portsin. (mm)

Flow Area

in.2 (cm2)

Makeup Lengthft (m)

Maximum OperatingPressurepsi (bars)




120038049

2 3/8 (60.33) EUE 8 Rd Box ×

2 7/8 (73.03) 6P Acme Box

3.38(85.85)

Non-full-bore

[email protected](25.4)

2.63(16.97)

2.37 (0.72)

20,000 (1380)

150,000 (68 000)

22,000 (1515)

22,000 (1515)

101016565

2 7/8 (73.03) EUE 8 Rd Box × 2 7/8 (73.03) 6P

Acme Box

3.88 (98.55)

Non-full-bore

[email protected] (25.4)

3.93(25.34)

2.43(0.74)

20,000 (1380)

170,000(77 000)

15,000 (1035)

15,000 (1035)



Annular Pressure-Control Line Swivel Sub

When run in conjunction with the annular pressure-control line (APF-C) firing head, the APF-C swivel sub provides a swivel point between the guns and packer when it is desired to have the guns rotate freely as when orienting shots in a deviated well.


• Compatible with APF-C firing head and control line

• Can be run anywhere between the packer and the firing head

• Transmits pressure through the control line while rotating

Operation

The APF-C swivel is made up in the string between the packer and the firing head. A section of control line is made up from the packer to the top of the swivel. A second section of control line is made up from the bottom of the swivel to the APF-C firing head. Annulus pressure is transmitted from the packer, through the swivel to the firing head.

APF-C Swivel Sub

HA

L1

05

39

Annular Pressure-Control Line (APF-C) Swivel Sub Specifications

SAP No.


Maximum ODin. (mm)

Minimum IDin. (mm)




Make-up Lengthft (m)

101230619 2 7/8 EU 8rd Box × Pin

5.13(130.30)

2.0(50.8)

200,000(90 718) NA* NA* 1.3

(0.39)

*The APF-C swivel sub is not designed to operate with differential pressure.


Annular Pressure-Control Line Tubing Release

The 2 7/8-in. annular pressure-control line tubing release assembly (APF-C TR) provides a mechanical method of releasing the APF-C firing head and VannGun® assembly from the tubing string.


• Releasing the gun assembly opens the tubing for other tools such as production logging, testing, and treating

• Low cost method to release gun assembly

• Utilizes off-the-shelf shifting tools

• No time limit on dropping the gun assembly

• Leaves perforations uncovered and helps eliminate flow restriction

Operation

The APF-C TR is run between the APF-C firing head and the 7- or 9 5/8-in. annulus pressure transfer reservoir (APTR). The control line for the APF-C is attached to the control line housing, which transfers the pressure through the APF-C TR and out the finger sub to a second control line. The second control line transfers the pressure down to the APF-C firing head. Releasing can be accomplished by the use of a standard Halliburton or Garret shifting tool.

APF-C Tubing Release (APF-C TR)

HA

L1

05

89

Annular Pressure Control Line Tubing Release (APF-C TR) Specifications

SAP No.Upper Thread Size

and TypeLower Thread Size

and Type

Makeup Lengthft (m)

Maximum ODin. (mm)

Minimum IDin. (mm)


Burst Pressurepsi (bar)


879212 7/8 EUE 8 Rd Box(73.03 mm EUE 8 Rd

Box)

2 7/8 EUE 8 Rd Pin(73.03 mm EUE 8 Rd Pin)

2.24(0.68)

4.62 (117.35)

Latch Sizes – 1.88 (47.75), 2.125 (53.98),

or 2.25 (57.15)

120,000(54 431)

12,000(827)

11,000(758)


Bar Pressure Vent

The bar pressure vent (BPV) is designed to achieve a differential pressure between the formation and tubing string. This tool helps to safely allow a differential pressure in wells with existing open perforations or in unperforated wells. The BPV is an internal sliding-sleeve tool actuated by pressure in the tubing. It is run between the packer and the guns.


• Offers an inexpensive way to create the necessary underbalance

• Allows the hole to be totally contained at the wellhead before the surge

• Allows the sleeve to lock in place once the port is opened

• Can be run with any packer

• Does not rely on tubing manipulation (Hydrostatic pressure in the tubing is the only force required.)

Operation

The BPV consists of a ported housing and a sliding sleeve. The sliding sleeve is isolated from the tubing pressure by a break plug with a hollow center.

The BPV is activated when the detonating bar is dropped through the tubing and shears the hollow break plug. This action allows the pressure in the tubing to force the sleeve upward, uncovering the ports. A lock ring locks the sleeve open. The detonating bar continues downward to strike the firing head.

If the vent must be opened before dropping the detonating bar, dropping a special tube will open the vent and not fire the guns. When the bar is dropped, it will pass through the tube and fire the guns.

Bar Pressure Vent (BPV)

HA

L10565

Bar Pressure Vent (BPV) Specifications

SAP No.


Maximum OD

in. (mm)

Minimum ID

in. (mm)


Flow Area

in.2 (cm2)

Makeup Lengthft (m)



MaximumDifferential Pressure psi (bars)




1012019512 3/8 (60.33)

EUE 8 Rd Box × Pin

3.06(77.72)

1.50(38.10)

4 @ 1.0 (25.40)

1.77(11.40)

1.30(0.40)

20,000(1380)

1,000(69)

8,000(550)

140,000(63 400)

24,000(1655)

20,000(1380)

1001557882 3/8 (60.33)

EUE 8 Rd Box × Pin

3.63(92.20)

1.90(48.26)

4 @ 1.0 (25.40)

3.14 (20.27)

1.30(0.40)

15,000(1035)

1,000(69)

8,000(550)

146,000(66 200)

18,000(1240)

22,000(1515)

1000103282 7/8 (73.03)

EUE 8 Rd Box × Pin

3.88(98.55)

2.25(57.15)

4 @ 1.13 (28.70)

3.98(25.65)

1.40(0.43)

15,000(1035)

1,000(69)

8,000(550)

160,000(72 500)

19,000(1310)

17,000(1170)

1001557893 1/2 (88.90)

EUE 8 Rd Box × Pin

5.0 (127.0)

2.75(69.85)

4 @ 1.75 (44.45)

5.94(38.32)

1.57(0.48)

15,000(1035)

1,000(69)

8,000(550)

400,000(181 400)

22,000(1515)

18,000(1240)



Below-Packer Vent Device

The below-packer vent device (BPVD) was developed for use with the annulus-pressure crossover assembly (APCA). Surface pressure applied to the annulus is transmitted through the APCA to a closed chamber below the BPVD and above a pressure-responsive firing head. The BPVD can be set to work before or after the perforating assembly is detonated.


• Does not require tubing hydrostatic pressure to operate

• Can operate in highly deviated wells

• Can be used in wells with low formation pressure

• Eliminates nitrogen requirements

• Helps allow maximum underbalance

• Is compatible with several types of firing heads

• Can provide reliable and accurate pressure response

Operation

To open the BPVD, a predetermined annulus pressure is transmitted through the APCA to below the BPVD. This pressure then ruptures a disk in the lower housing of the BPVD. An actuating piston then forces the venting sleeve away from the production ports. This action establishes communication with the tubing string.

Below-Packer Vent

HAL

1545

0

Below-Packer Vent Device (BPVD)

HAL

1545

1

Below-Packer Vent Device (BPVD) Specifications

SAP No.


Maximum ODin. (mm)

Minimum IDin. (mm)

Makeup Lengthft (m)







1001557872 3/8 (60.33)

EUE 8 Rd Box × Pin

3.38(85.85)

Non-full-bore

2.32(0.71)

4 @ 1.0(25.4)

15,000(1035)

1,000(69)

150,000(68 000)

25,000(1725)

22,000(1515)

1000141762 7/8 (73.03)

EUE 8 Rd Box × Pin

3.88(98.55)

Non- full-bore

2.26(0.69)

5 @ 1.0(25.4)

15,000(1035)

1,000(69)

170,000(77 000)

25,000(1725)

25,000(1725)



Maximum Differential Bar Vent

The maximum differential bar vent (MDBV) assembly is run between the perforating guns and the packer. After the packer is set, the opening of the vent creates communication between the tubing and the rathole. The vent is opened by breaking the plug inside the tool and allowing the sleeve to uncover the ports. Running the MDBV allows the operator to run the tubing in the well with no hydrostatic pressure in the tubing.


• Operates with a minimum amount of fluid in the tubing

• Helps allow maximum differential pressure when perforating in low-pressure formations

• Does not depend on tubing hydrostatic pressure to operate

• Assisted mechanically by an operating spring to help ensure full and complete opening

• Can be used in wells with open perforations to achieve an underbalance when guns are fired to add new perforations

Operation

The maximum differential bar vent is held closed by a chamber of silicone fluid, which keeps a spring compressed. When the silicone fluid is released from the chamber, the spring extends and opens the vent. Once the break plug is broken, the silicone fluid drains into the tubing.

The MDBV will open with up to 1,000 psi (68.95 bar) in the tubing regardless of rathole pressure. If there is more than 1,000 psi (68.95 bar) in the tubing, and there is uncertainty about the rathole pressure, consider the bar pressure vent instead of the MDBV.

If the vent must be opened before dropping the detonating bar, dropping a special tube will open the vent and not fire the guns. When the bar is dropped, it will pass through the tube and fire the guns.

Maximum Differential Bar Vent

HAL

1544

5

Maximum Differential Bar Vent (MDBV) Specifications

SAP No.


Maximum OD

in. (mm)

Minimum ID

in. (mm)


Flow Area of Ports

in.2 (cm2)

Makeup Lengthft (m)

Temperature Rating

(Limited by silicone fluid)

°F (°C)



CollapsePressurepsi (bars)

1000052912 3/8 (60.33)

EUE 8 Rd Box × Pin

3.36(92.20)

2.0(50.80)

5 @ 1.0(25.40)

3.92(25.29)

2.29(0.70)

350(176)

221,000(100 200)

19,500(1345)

16,500(1135)

1000052942 7/8 (73.03)

EUE 8 Rd Box × Pin

3.88(98.55)

2.2 (57.15)

4 @ 1.13(28.70)

4.01(27.87)

2.39(0.73)

350(176)

231,000(104 700)

19,000(1310)

13,000(895)

1001568533 1/2 (88.9) EUE 8 Rd Box × Pin

4.50(114.30)

2.7 (69.85)

4 @ 1.75(44.45)

9.58(61.81)

2.75(0.84)

350(176)

245,000(111 000)

14,000(965)

14,000(965)




The pressure-operated vent (POV) is designed to achieve a differential pressure between the formation and tubing string and to provide a way to open the vent and test the packer before the guns are fired.

When the guns have been positioned and the packer has been set, the predetermined amount of fluid is added to the tubing. Adding the fluid into the tubing causes the POV to open and creates the proper pressure differential before firing. Nitrogen may also be used with or in place of the fluids to obtain the necessary hydrostatic pressure in the tubing.


• Allows the vent to be opened without the guns being fired

• Allows the packer to be tested before the guns are fired

• Fills tubing automatically when run with Vann™ circulating valve

• Can be run with mechanical or pressure-actuated firing heads

• Useful in highly deviated wells

• Compatible with other packers

Operation

The POV consists of a ported housing, a sliding sleeve, and a set of shear pins. The sleeve is held in the closed position by a variable number of shear pins. The pins are isolated from annular pressure and are only exposed to the tubing hydrostatic. The POV will open when the proper amount of hydrostatic pressure is applied to the shear pins. The amount of hydrostatic it takes to open the POV depends on how many shear pins are installed in the tool. When the pins shear, the hydrostatic pressure forces the sleeve upward, which uncovers the flow ports. The sleeve is then locked into the open position.

Pressure-Operated Vent (POV)

HA

L1

05

38

Pressure-Operated Vent (POV) Specifications

SAP No.


MaximumOD

in. (mm)

Minimum ID

in. (mm)


Total Flow Areain.2 (cm2)

Makeup Lengthft (m)



Maximum Differential Pressure psi (bars)




1012972982 3/8 (60.33)

EUE 8 Rd Box × Pin

3.06(77.72)

1.50(38.10)

4 @ 1.0(25.40)

1.77(11.40)

1.30(0.40)

20,000(1380)

1,000(69)

8,000(550)

140,000(63 400)

24,000(1655)

20,000(1380)

1000141772 3/8 (60.33)

EUE 8 Rd Box × Pin

3.63(92.20)

1.90(48.26)

4 @ 1.0(25.40)

3.14(20.27)

1.30(0.40)

15,000(1035)

1,000(69)

8,000(550)

146,000(66 200)

18,000(1240)

22,000(1515)

1000141782 7/8 (73.03)

EUE 8 Rd Box × Pin

3.88(98.55)

2.25(57.15)

4 @ 1.13(28.70)

3.98(25.65)

1.40(0.43)

15,000(1035)

1,000 (69)

8,000(550)

160,000(72 500)

19,000(1310)

17,000(1170)

100014793 1/2 (88.90)

EUE 8 Rd Box × Pin

5.0(127.0)

2.75(69.85)

4 @ 1.75(44.45)

5.94(38.32)

1.57(0.48)

15,000(1035)

1,000(69)

8,000(550)

400,000(181 400)

22,000(1515)

18,000(1240)



Vann™ Circulating Valve

The Vann™ circulating valve (VCV) is designed to be used as a fill-up valve or as a circulating valve for displacing well fluids before setting a packer. After the fluid is displaced, the operator applies pressure to the tubing or annulus to rupture a disk and close the VCV.


• Can be used as a circulating and shutoff valve

• Often run with other venting or production devices

• Economical and reusable

Operation

The VCV consists of a ported housing, a sliding sleeve, and a rupture disk, which must be ordered separately. The sliding sleeve, which has two air chambers, is open while the tool is run in the hole.

The rupture disk is available for different pressure ratings as needed. The amount of hydrostatic pressure required to actuate the VCV depends on the rating of the rupture disk.

Once the disk ruptures, the hydrostatic pressure enters the lower air chamber through the ruptured disk, forcing the sliding sleeve upward to cover the flow ports. Operating pressure can be pump-pressure applied after the VCV is at the bottom of the well or applied by hydrostatic pressure when the tool is run in the hole.

Vann™ Circulating Valve (VCV)

HAL

1544

7

Vann™ Circulating Valve (VCV) Specifications

SAP No.


MaximumOD

in. (mm)Minimum ID

in. (mm)


Flow Area of Ports

in.2 (cm2)

Makeup Lengthft (m)

MaximumOperating Pressure psi (bars)





1010153722 3/8 (60.33)

EUE 8 Rd Box × Pin

3.38(85.85)

1.875(47.62)

4 @ 1.0(25.4)

3.14(20.26)

1.96(0.60)

15,000(1035)

1,000(69)

225,000(102 000)

22,000(1515)

18,000(1250)

1200384562 7/8 (73.03)

EUE 8 Rd Box × Pin*

4.65(188.11)

2.12(53.85)

6 @ 1.0(25.4)

4.71(30.39)

3.25(0.99)

15,000(1035)

1,000(69)

392,000(177 700)

20,000(1380)

18,000(1250)

*Optional connections are 2 7/8-IF and 3 1/2-IF.These ratings are guidelines only. For more information, consult your local Halliburton representative.


Automatic Release

The automatic release (AR) allows the perforating guns to drop immediately after firing.


• Can be used with most mechanical and pressure-actuated firing heads

• Allows for immediate release of the guns

• Leaves the tubing fully open after the guns are released

• Eliminates the need to run wireline to shift the guns

• Reduces the chance of the gun’s sticking because of debris

Operation

The AR allows for dropping the perforating guns after they are fired. The guns may be fired either mechanically or by pressure. The releasing device is actuated by the pressure generated outside the perforating guns upon detonation, so the guns are released as soon as they fire.

Automatic Release (AR)

HA

L1

05

12

Automatic Release (AR) Assemblies List

SAP No. Description

100005225 2 3/4-in. Auto Release with Mechanical Firing Head

100005226 2 3/4-in. Auto Release with Mechanical Firing Head Model II-D



100155754 3 3/8-in. Auto Release with Mechanical Firing Head Model III-D

100005235 3 3/8 in. Auto Release with 2 1/2-in. TDF

100014158 3 3/8-in. Auto Release-High Pressure with 2 1/2-in. TDF

100010045 3 3/8-in. Auto Release-High Pressure with Mechanical Firing Head

101313281 3 3/8-in. Auto Release Firer with 2 1/2 in. TDF (3 1/2 NK3SB)



101205564 3 1/2-in. Auto Release Firer, Low Pressure with Model II-D

101294470 3 1/2-in. Auto Release Firer with 2 1/2 in. TDF

101313282 3 1/2-in. Auto Release Firer with Model II-D



101213155 4 1/2-in. Auto Release Firer Low Pressure with Model II-D



101313025 5 1/2-in. Auto Release Firer with Model II-D

101310170 5 1/2-in. Auto Release Firer with Model II-D or III-D



Automatic Release (AR) Specifications


in. (mm)

Maximum OD

in. (mm)

ID After Releasein. (mm)

Makeup Lengthft (m)



Maximum Differential Pressurepsi (bars)


100005225 2 3/8 (60.33) EUE 8 Rd 2.88(73.15)

2.125(53.98)

2.06(0.63)

20,000(1380)

1,500(103)

15,000(1035)

49,500(22 400)

100005226 2 3/8 (60.33) EUE 8 Rd 2.88(73.15)

2.125(53.98)

2.06(0.63)

20,000(1380)

1,500(103)

15,000(1035)

49,500(22 400)

100005233 2 7/8 (73.03) EUE 8 Rd 3.38(85.85)

2.72(69.09)

2.23(0.68)

20,000(1380)

1,500(103)

10,000(690)

68,000(30 800)

100005234 2 7/8 (73.03) EUE 8 Rd 3.38(85.85)

2.72(69.09)

2.23(0.68)

20,000(1380)

1,500(103)

10,000(690)

68,000(30 800)

100005235 2 7/8 (73.03) EUE 8 Rd 3.38(85.85)

2.72(69.09)

2.23(0.68)

20,000(1380)

1,500(103)

10,000(690)

68,000(30 800)

100155754 2 7/8 (73.03) EUE 8 Rd 3.38(85.85)

2.72(69.09)

2.23(0.68)

20,000(1380)

1,500(103)

10,000(690)

68,000(30 800)

100014158 2 7/8 (73.03) EUE 8 Rd 3.38(85.85)

2.52 (64.186)

2.23(0.68)

20,000(1380)

500(34)

17,000(1170)

68,000(30 800)

100010045 2 7/8 (73.03) EUE 8 Rd 3.38(85.85)

2.52 (64.186)

2.23(0.68)

20,000(1380)

500(34)

17,000(1170)

68,000(30 800)

100005236 3 1/2 (88.90) EUE 8 Rd 3.78(96.01)

2.99(75.95)

2.23(0.68)

20,000(1380)

1,500(103)

10,000(690)

68,000(30 800)

100156106 3 1/2 (88.90) EUE 8 Rd 3.78(96.01)

2.99(75.95)

2.23(0.68)

20,000(1380)

1,500(103)

10,000(690)

68,000(30 800)

100155752 4 1/2 (114.30) OD Box 4.5(114.30)

3.67(93.22)

2.23(0.68)

20,000(1380)

1,500(103)

9,500(655)

115,000(52 100)


Automatic Release (AR) Assemblies List

SAP No. Description


Mechanical Tubing Release

The mechanical tubing release (MTR) provides operators with the option of keeping or releasing the VannGun® assembly from the tubing string. The MTR is usually run above the firing head and below the production ports below the packer. A standard shifting tool is used to operate the release mechanism in the MTR.


• Frees the tubing for other tools and operations such as logging, production testing, and treating

• Provides a low-cost way to release the gun assembly

• Uses standard off-the-shelf shifting tools

• Does not have a time limit on dropping the gun assembly

• Leaves perforations uncovered to eliminate flow restrictions

Operation

The MTR consists of three main components: the upper housing, a lower finger release sub, and a latch. The latch retains the finger release sub in the housing. To operate the MTR, the user must do the following:

1. Select the proper shifting tool and run it into the hole on slickline through the MTR.

2. Pick back up to engage the latch and lightly jar the latch four or five times.

3. Go back down to verify the release of the VannGun assembly.

Mechanical Tubing Release (MTR)

HAL

1543

5


Mechanical Tubing Release (MTR) Specifications

SAP No.(without latch)


Maximum OD

in. (mm)

Minimum ID (latch size)

in. (mm)




MakeupLengthft (m)

100005286 2 3/8 (60.33) EUE 8 Rd Box × Pin

3.06(77.22)

1.50 (38.10) 111,500

(50 576)12,000(825)

10,000(690)

1.50(0.46)

1.63 (41.40)

1.81 (45.97) 111,500

(50 576)12,000(825)

11,000(760)1.88

(47.75)

100005281 2 7/8 (73.03) EUE 8 Rd Box × Pin

3.38(85.85)

1.88 (47.75)

111,500(50 576)

12,000(825)

11,000(760)

1.63(0.50)

2.13 (53.98)

2.25 (57.15)

100005284 3 1/2 (88.9) EUE 8 Rd Box × Pin

3.95(100.33)

2.25 (57.15) 111,500

(50 576)11,000(760)

10,000(690)

1.88(0.57)2.75

(69.85)

101236790 5 (127) 15 lb (6.8 kg) New Vam Box × Pin

5.59(142.01)

3.69 (93.68)

111,500(50 576)

12,000(825)

11,000(760)

3.60(1.10)

Mechanical Tubing Release (MTR) Shifting Tool and Key Number

Latch Sizein. (m) Tool No. Key No.

Key Maximum Exp. ODin. (mm)

Key Minimum ODin. (mm)

1.50 (38.10) 42 B 0120

42 B 108 1.626 (42.275)

1.49 (37.85)

42 B 443 1.70 (43.18)

1.422 (36.119)

1.625 (41.28) 42 B 0121 42 B 80 1.890

(48.006)1.593

(40.462)

1.81 (45.97)

42 B 0117 42 B 37 2.078 (52.781)

1.75 (44.45)

42 B 0237 42 B 681 2.12 (53.85)

1.69 (42.93)

1.88 (47.75)

42 B 0116 42 B 153 2.109 (53.569)

1.84 (46.74)

42 B 0117 42 B 37 2.078 (52.781)

1.750 (44.45)

42 B 0237 42 B 681 2.12 (53.85)

1.69 (42.93)

2.25 (57.15) 42 B 0118 42 B 287

42 B 462.593

(65.862)2.156

(54.762)

2.125 (53.98) 42 B 0159 42 B 387 2.44

(61.98)1.97

(50.04)

2.75 (69.85) 42 B 0147 42 B 348 2.952

(74.981)2.718

(69.037)



Pressure-Actuated Tubing Release

The pressure-actuated tubing release (PATR) is used to separate the guns from the toolstring when mechanical or slickline devices are not desirable. When separated, the guns drop off of the production tubing. Once the guns drop away, other tools and operations have no restrictions through the end of the tubing. In fact, the housing attached to the string has a greater ID than the tubing.


• Leaves the tubing string fully open

• Ideal for use in remote areas where wireline is expensive or unavailable

• Ideal for situations where wireline can cause a safety hazard

• Provides access to the wellbore for production logging tools

• Especially suited for releasing guns prior to stimulation treatments

Operation

The PATR consists of four main components: an upper housing, lower finger release sub, inner sleeve, and retaining latch. The PATR is pressure-balanced until the standing valve is dropped into the inner sleeve.

Tubing pressure is applied to shear the retaining pins in the latch. Once the latch has been shifted, the finger release sub with the sleeve releases from the housing and drops the perforating assembly into the rathole.

HA

L1

05

31

Pressure-Actuated Tubing Release (PATR)

Standing Valve

HAL

1544

2

Pressure-Actuated Tubing Release (PATR) Specifications

SAP No.


Maximum ODin. (mm)

Minimum ID Before

Releasein. (mm)

Minimum ID After

Releasein. (mm)

Standing Valve ODin. (mm)

Makeup Lengthft (m)




100156751 2 3/8 (60.33) EUE 8 Rd Box × Pin

3.38(85.85)

1.63(41.40)

2.31(58.67)

1.76(44.70)

1.73(0.53)

90,000(40 800)

10,000(670)

9,000(620)

100156744 2 7/8 (73.03) EUE 8 Rd Box × Pin

3.75(95.25)

1.812(46.02)

2.828(71.83)

1.86(47.24)

1.72(0.52)

120,000(54 400)

10,000(670)

10,000(670)

101015385 3 1/2 (88.9) EUE 8 Rd Box × Pin

4.19(106.43)

1.812(46.02)

3.5(88.90)

1.86(47.24)

1.71(0.52)

130,000(58 900)

10,000(670)

10,000(670)



DPU® Downhole Power Unit

The DPU® downhole power unit firing head is an electromechanical device that is designed to produce a linear force that activates a pressure-assisted firing device. The pressure-assisted device fires the perforating guns. Before the DPU firing head was used to activate the pressure-assisted firing device, this type of perforating gun activation was run on tubing. The pressure-assisted firing device was previously activated by dropping a device from the surface. The DPU firing head is run on slickline.

For the DPU firing head to begin activation, several parameters must be present.

• Pressure setting: The DPU firing head has a surface-selected downhole pressure setting that must be met. Any time the well pressure at the DPU firing head drops below the selected pressure setting, the DPU firing head activation sequence is stopped.

• Downhole Temperature: The DPU firing head requires a precise surface-selected downhole temperature. Any time the well temperature drops below the selected temperature setting, the DPU firing head activation sequence is stopped.

• Tool Movement: The DPU firing head has an accelerometer that detects tool movement. If the accelerometer detects motion, the other operating parameters are inactive.

• Surface-Selected Timer: The DPU firing head has a surface-selected timer that is activated if the three previous parameters are present.

If these four parameters are present, the DPU firing head is activated and the rod begins to stroke out. Rod travel takes approximately 20 minutes before contracting the pressure-assisted firing device. When the DPU firing head rod contacts the pressure-assisted firing device, a pin is sheared and perforating is activated. After initial activation, the DPU runs for 25 minutes and then turns off.

The 3.66 OD DPU and 2.50-in. DPU firing head can be converted to run either the Model II-D or the Model III-D pressure-assisted firing heads.

Conversion Kits for DPU® Downhole Power Unit

Assembly No. SAP No.Maximum OD

in. (mm)

146DFH20 00050531 3.66(93.96)

146DFH11 00050462 2.50(64.50)

Fish Neck

PressureTemperatureSwitch

Firing HeadPC Board

DPUDownholePower Unit

®

DPU PowerRod

Push Guide

Model IIIFiring Head

Adapterto GunsH

AL

15

99

0

DPU PowerRod

®

Push Guide

Model IIIFiring Head

Adapterto Guns

HA

L1

59

88

DPU® Downhole Power Unit


SmartETD® Advanced Electronic Triggering Device

The SmartETD® tool is an advanced electronic triggering device that provides an accurate, safe, and reliable method to run and fire downhole explosive tools using slickline. With its built-in sensor and memory capabilities, it can record and store downhole temperature and pressure data that can be used by the slickline specialists to program firing parameters.

The SmartETD tool requires four parameters to be met prior to firing. These are motion, time (preset), pressure (preset), and temperature (preset). The timing sequence begins when the tool is exposed to pressure. After the tool stops, any motion resets the electronic timer. After the SmartETD timer has remained motionless for a specific period of time and has simultaneously encountered the preset temperature and pressure windows, it initiates the firing sequence. The SmartETD tool can log memory settings for pressure and temperature readings up to 12k data sets.

The SmartETD tool will fire the Halliburton rig environment RED® detonator, as well as API RP-67-compliant devices. It is also capable of resisting detonation.

SmartETD® Tool

SmartETD® Specifications

Features

SAP No.

101038328

146ETD14Optional No-Blow

No-Drop Assembly

Diameterin. (mm)

1.690(42.93)

Lengthin. (mm)

60(1524)

Max. Temperature°F (°C)

300(149)

Max. Pressurepsi (bar)

15,000(103.42)

Control Parameters

Pressure yes (programmable)

Temperature yes (programmable)

Time yes (programmable)

Motion yes

Tension no

Resist Detonation Capability yes

HES RED® Capability yes

Memory Logging

Pressure yes

Temperature yes

No. of Points (reading) 12k data sets

No-Blow, No DropAssembly

Top Shock/CentralizerQuick Lock Assembly

Smart ETD Tool®

HV Shooting Module

Adapter

Selectable MechanicalPressure Switch

Shock Absorber

DetonatorSub/Explosivesas required withSTD 1 3/8-in. GO™Connection

VannGun Assembly®

HAL

1539

8


Coiled Tubing Conveyed Perforating

Conveying perforating guns to the zone of interest with coiled tubing has been effectively used for many years in a variety of applications. Benefits include faster run-in times when compared to conventional methods. And the guns can be detonated either with wireline or a pressure-activated firing head. Some of the applications include:

Perforating in Underbalanced Conditions

• Underbalanced conditions occur when hydrostatic pressure in the well is lower than formation pressure. Perforation under these conditions allows increased flow from the formation, which helps clean the perforations and helps reduce near-wellbore damage.

Horizontal Well Perforating

• Coiled tubing conveyed perforating could be deployed in horizontal portions of the well where conventional methods of perforating are impractical or impossible.

Coiled Tubing Used as the Production String

• The coiled tubing that conveys the perforating guns can also be used as the production tubing after well completion.

Special features include an automatic-release gun hanger, which allows the coiled tubing to detach from the perforating guns before they are fired, avoiding damage to the coiled tubing. A modular gun system is also available in which the perforating guns are loaded at the surface, deployed downhole individually, and stacked at the perforating zone. This method helps eliminate any gun length restrictions caused by the lubricator.

Correlation Tool Stack

Perforating Gun String

*Pressure relief ports are added to the BHA for coiled tubing perforating jobs to help eliminate the possibility of a pressure increase due to thermal expansion in a closed chamber.

Coiled TubingConnector

Swivel

Back PressureValve

HydraulicDisconnect

CirculatingValve

Crossover

Centralizer

BatteryHousing

MemoryController

Pressure

Casing CollarLocator (CCL)

Gamma/RayTemperature

RollerCentralizer

HA

L1

53

99

Coiled TubingConnector

Swivel

Back PressureValve

HydraulicDisconnect

Pressure ReliefPorts*

Coiled Tubingand Firing HeadCrossover

Firing Headwith CirculatingPorts

3 3/8-in.-6TTPScalloped Guns

HA

L1

54

00


Fill Disk Assembly

The fill disk assembly (FDA) is used where either packer selection or well conditions preclude the use of a venting device. The FDA is used in place of a perforated sub and replaces the balanced isolation tool (BIT) in wells with reasonably clean fluids. The glass disk prevents debris from settling on the firing head. Pressure is equalized across the glass disk.

The FDA is run between the firing head and packer. The recommended minimum distance from the FDA to the firing head is 30 ft.


• Allows debris to be circulated off the glass disk through the flow ports above the glass disk

• Acts as a perforated sub for circulating fluid displacement with nitrogen and swabbing

• Can be run with either a mechanical or pressure-actuated firing head

Operation

The FDA consists of a ported housing with a glass disk installed in the ID across the lower set of ports. The disk is not sealed, so pressure can equalize across the glass. Any debris falling out of the tubing or fluid above the glass should land on the glass disk. This debris can be circulated off the disk, or if it is not a large amount, it will be displaced out the ports by the detonating bar falling through it.

Once the bar breaks through the disk, it should fall in clean fluid all the way to the firing head. In mud systems or wells with a known debris problem, the balanced isolation tool is recommended in place of the FDA.

Fill Disk Assembly

(FDA)

HA

L8

35

2

Fill Disk Assembly (FDA) Specifications

SAP No.


Maximum OD in. (mm)

Minimum ID in. (mm)

Flow Area in.² (cm²)

Number of Ports


Makeup Lengthft (m)

100005295 2 3/8 (60.33) EUE8 Rd Box × Pin

3.01(76.45)

1.98(50.29)

6.28(40.54) 8 120,000

(54 431)0.76

(0.23)

100005297 2 7/8 (73.03) EUE 8 Rd Box × Pin

3.51(89.15)

2.44(61.98)

7.88(50.8) 8 150,000

(68 039)0.71

(0.22)

100005299 3 1/2 (88.90) EUE 8 Rd Box × Pin

4.20(106.68)

3.0(76.20)

14.13(91.20) 8 200,000

(90 718)0.69

(0.21)


Gun Guides

Gun guides were developed by Halliburton to maintain the proper orientation of guns attached to the short string in a dual completion. The gun orientation must be maintained so that the charges shoot away from the long string. Gun guides are also used with Y-blocks in dual-string and single-string completions.

There are two types of gun guides. The delta-shaped or dual gun guide can be used when the casing ID is the same from top to bottom. If the casing at the top of the well is larger, then the wraparound guide must be used. The wraparound type may also be used in the wellbores with the same ID top to bottom.

Guides are available for most of the smaller size guns (3 3/8 in. or 85.73 mm and smaller) that are typically run on the short string side of a dual completion.

Dual Completion with Gun Guides

HA

L1

05

77

HA

L6

19

0

Dual Completion with Dual Gun Guide

Dual Completion with Wraparound Gun Guide

VannGunAssemblies

®


Tubing Release

VannGunAssemblies

Permanent orRetrievable Packer

VannGunAssemblies

VannGunAssemblies

Gun Guide

Gun GuideH

AL

15

39

5

Dual HydraulicSet Packer

BalancedIsolation Tool

MechanicalFiring Head



EZ Pass™ Gun Hanger

The EZ Pass™ gun hanger is designed to be run in conjunction with Halliburton’s Modular Gun System. This advanced design includes slips that stay retracted within the slip housing until the tool is set. After the perforating event, the slips will return to the running position and the tool auto releases.

If desired, the hanger can be fished with a standard pulling tool and retrieved from the well.


• Running and setting procedures are similar to common bridge plugs and sump packers—uses standard setting equipment

• Can be set in larger ID after running through restrictions

• Retrievable and redressable

• May be configured to auto-release or stay set after gun detonation.

• Can be deployed on wireline, tubing, or coiled tubing

• One size sets in multiple casing ranges.

Operation

The EZ Pass gun hanger can be run independently or attached to the gun system.

If the gun hanger is run attached to the perforating assembly, it must be actuated using pressure. The assembly would be run in, positioned, and then pressure would be applied to the wellbore to set the tool. No explosive components would be necessary for this operation.

If the gun hanger is deployed and positioned similar to a wireline-set permanent or sump packer, the same power charge-type setting tools are used to set the hanger. After the setting tool is removed from the wellbore, the guns may be deployed as individual modules or as a complete assembly and are stacked on top of the hanger.

A releasing tool is needed to release the hanger and may be run on the bottom of the perforating assembly. When activated, the releasing tool fires a shaped charge and breaches the top of the hanger. This process allows the gun weight to be transferred to the inner mandrel, placing the hanger in the releasing position and forcing the slips away from the casing.

The EZ Pass gun hanger is designed with a 2.75 fishing neck and can be fished with a standard pulling tool. The slips will retract into the ID of the tool and helps allow it to be retrieved through a wellbore restriction.

EZ Pass™ Gun Hanger

HA

L1

27

94



EZ Pass™ Gun Hanger Specifications

Casing Size and

SAP No.

Casing Weights*

lb

Range of Casing IDs*

in. (cm)

Tool Maximum

OD (With Slips Retracted)

in. (cm)

MaximumOperating Pressure psi (bar)

Minimum Operating Pressure psi (bar)



Collapse Pressure psi (bar)

Overall Length

(Maximum) ft (mm)

Maximum Gun Weight

lb (kg)Weight lb (kg)

4 1/2101320360 9.5 - 15.1 4.09 - 3.826

(10.4 - 9.72)3.50

(8.89)18,000** (1241)

500 (34.5)

400 (204.4)

74,000 (33 600)

18,000 (1241)

5.1 (1.55)

30,000 (13 600)

116 (52.6)

5 1/2 101315538 20 / 23 / 26 4.778 - 4.548

(12.14 - 11.55)4.125 (10.5)

20,000** (1450)

500 (34.5)

400 (204.4)

74,000(33 600)

20,000 (1450)

5.1 (1.55)

30,000 (13 600)

165(74.8)

7 101321131 29 / 32 / 35 6.184 - 6.004

(15.70 - 15.25)5.375

(13.65)20,000** (1450)

500 (34.5)

400 (204.4)

74,000(33 600)

20,000 (1450)

5.1 (1.55)

30,000 (13 600)

180 (81.7)

*Recommended**Maximum Operating Pressure based on hydrostatic pressure and applied gun weight.The EZ Pass hanger does not have minimum ID or Burst Pressure requirements.NOTE: The EZ Pass gun hanger is designed with specific features to enhance its retrievability; however, due to the uncertainty of the wellbore conditions created by the perforating event, the retrieval of this tool cannot be assured.


Hydraulic Metering Release Tool for the Single Trip System (STPP™-GH)

The hydraulic metering release tool is one component of the single trip system that allows us to perforate and frac-pack a zone of interest in a single trip.

Numerous safety and economic benefits accompany this capability. These benefits become even more profound as well parameters become more severe. The ever-present goal is to reduce completion CAPEX and maximize net present value.


• Save rig time with reduced pipe trips for faster completions

• Minimize fluid loss and formation damage

• Minimize associated well control risks

• Perforate under- or overbalanced

• Perform the sand control option most suitable for your well (FP, HRWF, GP)

• Complete deep, hot zones where fluid loss pills are not effective

Hydraulic Metering Release Tool

HA

L1

57

80

Plug

Floating Piston

Metering Section

Silicone Fluid

Finger Release

Shear Screws

Stinger/Fishneck


Hydraulic Metering Release Assembly (Low Temperature)

Upper Thread Size

and Type

Lower Thread

Size and Type

Overall Lengthin. (cm)

Maximum OD

in. (cm)

Effective OD*

in. (cm)



Maximum Slack Off Weight on

Tool lb (kg)

Minimum Slack Off Weight on

Toollb (kg) Redressable

Weightlb (kg)

2 7/8 EU-RD N/A 45.47(369.49)

4.5(11.43)

4.5(11.43)

200(93.33)

97,700(44 315)

30,000(13 607)

13,600(6168) Yes 156.46

(70.96)5.5

(13.97)

7.5(19.05)

*Effective OD of the tool is dictated by the OD of the skirt to be used.**Maximum weight on gun hanger = gun weight + slackoff weight on hydraulic release tool.***The tool is assembled with four shear screws of 3,400 lb each.

Hydraulic Metering Release Assembly (High Temperature)

Upper Thread Size

and Type

Lower Thread

Size and Type

Overall Lengthin. (cm)

Maximum OD

in. (cm)

Effective OD*

in. (cm)



Maximum Slack off

Weight on Tool

lb (kg)

MinimumSlackoff

Weight on Tool

lb (kg) RedressableWeightlb (kg)

2 7/8 EU-RD N/A 45.47(369.49)

4.5(11.43)

4.5(11.43)

200-350(93.33-148.88)

97,700(44 315)

30,000(13 607)

13,600(6168) Yes 156.46

(70.96)5.5

(13.97)

7.5(19.05)

*Effective OD of the tool is dictated by the OD of the skirt to be used.**Maximum weight on gun hanger = gun weight + slackoff weight on hydraulic release tool.***The tool is assembled with four shear screws of 3,400 lb each.


App

endix

Appendix

United States Patents

Patent No. Patent Name Product Name

1,194,780 Accelerated Downhole Pressure Testing

1,196,570 Method for Controlling Subsurface Blowout

1,201,058 Firing of Well Perforation Guns

1,201,376 Bar Actuated Vent Assembly

1,201,379 Releasable Coupling

1,202,558 Perforating Gun Carrier and Method of Making

1,204,053 Drill Stem Test and Perforating System

1,208,516 Mechanically Initiated Tubing Conveyed

1,211,040 Gravity Oriented Perforating Gun for Use In

1,214,386 Well Completion Method and Apparatus

1,224,139 Pressure Responsive Explosion Initiator with Time Delay and Method of Use

1,224,407 Sidewall Core Gun

1,228,019 Charge Holder

1,234,042 Gun Firing Head

1,235,059 Redundant Detonation Initiators for Use in Wells

1,241,269 Borehole Devices Actuated by Fluid Pressure

1,259,560 Annulus Pressure Firer Mechanism with Releasable Fluid Conduit Force Transmission Means

1,259,561 Borehole Devices Disarmed by Fluid Pressure

2,105,004 Tubing Conveyed Selective Fired Perforating Systems

2,169,019 Differential Pressure Actuated Vent Assembly

4,544,034 Firing of Well Perforation Guns Early Model 3D or 2D

4,576,233 Differential Pressure Actuated Vent Assembly Pressure Op & Bar Vent

4,614,156 Pressure Responsive Explosion Initiator with Time Delay and Method of Use Original TDF

4,632,034 Redundant Detonation Initiators for Use in Wells Redundant Firing Above &

4,655,138 Shaped Charge Carrier Assembly

4,673,033 Tubing Conveyed Perforating Assembly Safety Device Original Shot Delay Signal, EM

4,693,314 Low Actuation Pressure Bar Vent Maximum Diff. Bar Vent

4,726,610 Annulus Pressure Firer Mechanism with Releasable Fluid Conduit Force Transmission Means APFC Release Device

4,732,211 Annulus Pressure Operated Vent Assembly Annulus Pressure Operated Vent

4,771,827 Automatic Drop-Off Device for Perforating Guns Automatic Release

4,836,109 Control Line Differential Firing Head Redundant APFC Firing Head

4,901,802 Method and Apparatus for Perforating Formation Y-Block Perforating

4,905,759 Collapsible Gun Assembly Collapsible Gun Spacers

4,911,251 Method and Apparatus for Actuating a Tubing Conveyed Perforating Gun Triple Actuated Mech Firing

4,917,189 Firing Mechanism with Sliding Sleeve Vent Valve Pumping Well Bypass Assembly

4,969,525 Firing Head For a Perforating Gun Assembly Multiaction Firing Head

5,007,344 Dual Firing System For a Perforating Gun Dresser Redundant Ballistic

5,062,485 Variable Time Delay Firing Head Extended Delay Assembly

Appendix 8-1

5,078,210 Time Delay Perforating Apparatus EDA between Guns

5,103,912 Method and Apparatus for Completing Deviated and Horizontal Wellbores Multizone Multi-Packer Y-Block

5,156,213 Well Completion Method and Apparatus Bottom Mounted Gun Hanger

5,223,665 Method and Apparatus for Disabling Detonation Detonation Interruption Device

5,224,545 Eccentrically Actuated Perforating Guns SPM Firing Head

5,287,741 Methods of Perforating and Testing Wells Using Coiled Tubing Perf & Test w/Coiled Tubing

5,287,924 Tubing Conveyed Selective Fired Perforating Systems Select Fire System I

5,301,755 Air Chamber Actuator for a Perforating Gun Air-Chamber Actuation Firing

5,303,772 Well Completion Method and Apparatus PBR Monobore Gun Hanger

5,353,875 Methods of Perforating and Testing Wells Using Coiled Tubing Coiled Tubing Perfing

5,355,957 Combined Pressure Testing and Selective Fired Perforating Systems Using Select Fire to Pressure

5,366,014 Method and Apparatus for Perforating a Well Modular Gun System

5,398,760 Methods of Perforating a Well Using Coiled Tubing Running Guns w/Hanger on CT

5,423,382 Apparatus for Releasing Perforating Gun Dresser Auto-Release

5,458,196 Through Tubing Gun Hanger Through-Tubing Gun Hanger

5,529,127 Apparatus and Method for Snubbing Tubing Conveyed Perforating Guns in and out of a Wellbore Ratchet Connector

5,603,379 Bi-Directional Explosive Transfer Apparatus and Method Bi-Directional Shooting Swivel

5,701,957 Well Perforator Isolation Apparatus and Method Perf Gun w/Ratch Latch on

5,778,979 Latch and Release Perforating Gun Connector and Method Auto-Latch I

5,823,266 Latch and Release Tool Connector and Method Auto-Latch II

5,957,209 Latch and Release Tool Connector and Method

5,992,289 Firing Head with Metered Delay SL Retrievable Hydraulic Delay

5,992,523 Latch and Release Perforating Gun Connector Auto-Latch IV

6,006,833 Method for Creating Leak-Tested Perforating Gun Assemblies Gun Pressure Testing Method

6,012,525 Single Trip Perforating Gun Assembly and Method Collapsible Centralizer

6,173,779 Collapsible Well Perforating Apparatus Collapsible Guns

6,237,688 Pre-Drilled Casing Apparatus and Associated Methods for Completing a Subterranean Well Pre-Drilled Casing

6,246,962 Method and Apparatus for Adaptively Filtering Noise to Detect Downhole Events

6,295,912 Positive Alignment Insert (PAI) With Embedded Explosive

6,298,915 Orienting System for Modular Guns

6,434,084 Adaptive Acoustic Channel Equalizer and Tuning Method-LICE

6,435,278 Firing Head/Perforating Gun Latching System and Associated Methods Slickline Retrievable Mechanical Firing Head

6,494,261 Apparatus and Methods for Perforating a Subterranean Formation Use Propellant to Open Pre-Weakened Spots in the Casing String

6,595,290 Internally Oriented Perforating Apparatus G-Force® Gun System

6,675,896 Detonation Transfer Subassembly and Method for Use of Same Shearable Safety Sub

6,684,954 Bi-directional Explosive Transfer Subassembly and Method for Use of Same Bi-Directional Knuckle Joint

6,708,761 Apparatus for Absorbing a Shock and Method for Use of Same Shock Absorber with Shear Rings

6,820,693 Electromagnetic Telemetry Actuated Firing System for Well Perforating Gun Telemetry Firing Head

6,755,249 Apparatus and Method for Perforating a Subterranean Formation Expandable Casing with Expendable Plugs

United States Patents

Patent No. Patent Name Product Name

8-2 Appendix

Frequently Asked Questions and Answers

General

Which is better—underbalanced or balanced perforating?

It depends on completion objectives and well conditions. Laboratory experiments and field observations have proven time and time again that when designed properly, lower perforation skin is achieved through underbalanced perforating. The concept of underbalanced perforating is to create a large pressure differential between the wellbore and the reservoir when the guns are fired to instantaneously move fluid through the newly created perforation tunnels. This fluid movement is what helps to remove crushed formation material and residual shaped charge debris, resulting in more efficient perforations. When proper underbalance pressure is not achieved, either due to operational issues or lack sufficient formation pressure, the result can be perforations that are not cleaned up completely, leading to reduced injectivity or higher pressure drawdown for production. In some cases where balanced perforating is the only option, it may be necessary to perform some type of remedial step such as acidifying or fracturing to stimulate the near-wellbore area.

Another alternative to underbalanced or balanced perforating is extreme overbalance perforating. This technique involves pressuring the wellbore with nitrogen above the fracture gradient of the formation to initiate perforation breakdown and mild fracturing near the wellbore. This method is especially effective when the reservoir pressure is insufficient to effectively surge the perforations clean.

Your Halliburton representative can provide an analysis of the factors affecting your well.

How is the optimum underbalance to yield clean perforations determined?

The maximum underbalance without sand production can be estimated based on the density of the shales above and below the sand or on sonic travel time. The minimum underbalance can be estimated using Halliburton’s PerfPro® Process.

Should the well be flowed after perforating?

Yes, in most cases, in order to:

• remove perforation debris prior to gravel packing.

• gather reservoir data including drawdown, effective permeability, skin damage, and productivity index.

• collect reservoir examples for analysis.

What volume should be flowed back after perforating?

One gallon per perforation is often used as a guide for back flow volumes.

How important is centralizing the guns when a gravel pack will be run?

Extremely. The guns must be centralized to provide uniform hole sizes around the casing and to maximize charge performance. Total flow area can be increased as much as 25% by centralizing the guns.

How much casing damage does perforating cause?

Studies show that cemented 7-in. and 9 5/8-in. casing can be perforated with phased shot densities up to 12 spf with a 0.76-in. hole without reducing crush resistance.

How much performance is lost when charge time and temperature rating is exceeded?

Charges begin to degrade immediately after time and temperature limits are exceeded. But, there is no way to quantify the degree of loss without testing the specific charges under identical conditions.

Halliburton time and temperature charts are based on data from tests on explosives which performed at maximum levels after exposure to time and temperature.

How much does shooting out of scallop reduce performance?

Testing on deep penetrating charges indicates a performance reduction of 10 to 15% depending on the charge and on gun size.

Appendix 8-3

When should backup firing heads be included in the perforating string?

Any time you want to minimize the risk of a misrun.

How can stuck guns be retrieved?

Several options are available.

Include jars in the TCP workstring in areas where stuck guns are common. Maximum pull on the string and jarring usually frees the guns.

A chemical cut can be made in the tubing below the packer to retrieve the packer and accessory tools. Then, an overshot/washpipe can be run so the fish can be washed over and retrieved.

Halliburton normally includes a safety joint in the perforating string. It separates above the stuck packer allowing the accessory tools to be retrieved. Then, an overshot or spear and jars can be used to jar the packer and guns free.

A safety joint can also be run below the packer. It allows the accessory tools to be pulled. Then, an overshot or a pin can be run in with jars.

What can be learned when gauges are run with the TCP string?

If the well is perforated underbalanced and surged, Halliburton’s FasTest® service can be used to analyze the data and produce reservoir pressure and permeability estimates.

How can fluid loss be controlled when killing the well?

Halliburton’s multi-position OMNI™ valve can be closed after perforating to hold completion fluids in the workstring. You can also spot a fluid loss pill across the formation after cycling the OMNI valve to its reversing position by applying annulus pressure.

Should 3 3/8-in. guns be run in 4 1/2-in. casing?

Though this is done frequently, usually without problems, Halliburton’s policy is to recommend only gun sizes that can be washed over with standard washover pipe in any particular casing size.

How compatible are Halliburton’s different types of explosives?

Halliburton uses four standard explosive types—RDX, HMX, HNS, and PYX. In tests, they have been found to be compatible in almost all configurations.

Any time more than one type of explosive is used in a system, the entire system will have a time and temperature rating equivalent to the lowest rated explosive.

StimGun™ System FAQs

How effective is the StimGun™ technique?

The procedure usually has a 95% success ratio as a perforation breakdown tool. As a stand-alone stimulation tool, it usually has a 45 to 50% success rate.

Can the StimGun assembly be used in horizontal wells?

Yes. The procedure has been very successful in horizontal wells. Standard perforation breakdown treatments such as the POWR*PERFSM and PerfStim™ processes are limited by the amount of energy that can be delivered through the tubing. They are not practical treatments for long intervals. StimGun sleeves, on the other hand, provide the energy at the perforations so long intervals can be treated effectively.

POWR*PERF, a process of Marathon Oil Company, is licensed by Halliburton. POWR*PERF is a service mark/trademark of Marathon Oil Company and licensed by Halliburton.StimGun is a trademark of Marathon Oil Company and is licensed to Halliburton by Marathon.PerfStim is a trademark of Oryx Energy Company. It is patented by Oryx and licensed by Halliburton.

8-4 Appendix

Can the StimGunSM service be used with limited entry perforating?

No. A minimum of 4 spf and at least 2 ft of perforations and a minimum of 3 ft of StimGun™ sleeve are required for a successful StimGun service. Otherwise, insufficient pressure is generated. The system is not compatible with limited entry type perforating or 0° shot phasings.

What are the StimGun sleeve’s temperature limits?

Standard sleeves can be used at temperatures to 250°F (52°C). High-temperature sleeves can be used up to 360°F (182°C).

Can StimGun sleeves be used in acid?

Yes. The sleeves are not acid reactive.

What sleeve sizes are available?

Sleeves are available for all VannGun® tools.

How much fluid should be run above the StimGun tool?

The sleeves require 500 psi of hydrostatic pressure to ensure proper burn. Fluid, not gas (nitrogen), should be used.

What can be learned by running the high-speed recorder?

The recorder monitors the StimGun sleeve’s burn and pressure regime. The pressure, acceleration, and strain data it records can be analyzed by the PulsFrac™ system and compared with the model’s preliminary output.

The data and results can be valuable in future completion design work.

Is gun centralization important?

Yes. When running the StimGun assembly, it is necessary to protect the sleeves from being damaged. The StimGun sleeves are similar to PVC piping and are very brittle. Therefore, the recommendation is to run a StimGun retaining collar top/bottom of each 3 ft sleeve in addition to gun centralization.

*PulsFrac is a trademark of John F. Schatz Research and Consulting, Inc.

What are the primary applications for the POWR*PERF™ system?

The system is excellent for cleaning up near-wellbore skin in low-pressure reservoirs with good permeability.

It also is an excellent choice for reservoirs with adjacent water or gas zones.

The service also can develop data for pre-frac evaluations by fracturing the reservoir and producing fluid samples. Shots can be oriented to the fracture plane, enhancing the value of the data gathered. In some cases, the data has shown that the reservoir is not viable, saving the costs of additional treatments.

The service should not be considered as a stand-alone treatment in reservoirs with less than 2-md permeability.

What criteria are used to choose between an underbalanced TCP job and a POWR*PERF systems job?

In general, if the reservoir has good permeability and sufficient reservoir pressure, it is a candidate for a natural (underbalanced) completion. If information from offset wells and/or charts from Halliburton’s PerfPro® process brochure indicate reservoir pressures are not sufficient, the well should be considered a POWR*PERF system candidate.

What special equipment is required to run a POWR*PERF system job?

Standard equipment for POWR*PERF system jobs includes Halliburton’s wellhead isolation tool, pop off valves to protect the annulus, and packers rated for at least 5,000 psi differential. A Halliburton nitrogen pumper usually is the only pumping equipment required.

Are special tubulars required?

No. The POWR*PERF system was designed to be an integral part of the completion string. In the vast majority of cases, standard oil country tubulars can be used. Pressure can be held on the backside to reduce differential across the tubing. The Halliburton wellhead isolation tool protects topside equipment.

Appendix 8-5

What rules of thumb can be used in designing a POWR*PERF™ system job?

A fluid column of no more than 300 ft should be run in the tubing above the POWR*PERF™ guns. Marathon studies show that friction losses become excessive with higher fluid levels. The fluid can be acid, brine, produced fluids, etc., or any fluid that is compatible with the formation.

The pressure gradient should be a minimum of 1.4 psi/ft—regardless of the reservoir’s frac gradient. This gradient helps overcome frictional losses and helps rectify frac gradient miscalculations.

Marathon studies show that pressure gradients of 100% to 200% over the frac gradient produce the best results. More is better whenever possible with this process.

The POWR*PERF process does not require additional pumping. However, Halliburton often recommends pumping one tubing volume of nitrogen after the guns fire to energize the formation, aiding in dislodging debris from low-pressure reservoirs.

What is the maximum interval length that can be effectively treated with the POWR*PERF process?

The practical limit at this time seems to be 60 to 70 ft. According to industry studies, lower sections of longer intervals do not benefit due to large pressure drops.

What ratio of POWR*PERF carrier to perforated interval should be used?

For the smaller 3 1/8-in. and 3 3/8-in. OD carriers, a 2:1 ratio should be used. For 4-in. and 4 1/2-in. OD carriers, a 1:1 ratio is sufficient.

What is the minimum shot density and phasing for POWR*PERF system jobs?

The POWR*PERF service requires a minimum of 6 spf and 60° phasing. The 6 spf increases flow area to the wellbore while 60° phasing aligns more perforations with natural frac planes.

For frac jobs in a number of wells, this minimum configuration eliminated tortuosity, screenouts, and reduced horsepower requirements.

Should Deep Penetrating or Big Hole charges be used?

Halliburton recommends Deep Penetrating (DP) charges at this time. Results from several jobs using Big Hole (BH) charges were unsatisfactory. Studies indicate that BH charges may create more fines, which inhibit fluid injection and may not be desirable for Extreme Overbalance.

Why is sintered bauxite used?

Bauxite offers excellent erosive qualities and high density. In tests at the velocities achieved in POWR*PERF service, frac sand shatters at the formation face.

What fluid velocities are produced during a POWR*PERF treatment?

Fluid velocities of 3,000 ft/sec and flow rates equivalent to 140 bbl/min per perforation occur at the moment of detonation. All fluid in the tubing evacuates in less than 5 seconds.

DrillGun™ FAQs

What advantages does the drillable gun system offer?

The system eliminates a wireline perforating trip during squeeze cementing operations. The squeeze-perforating DrillGun™ tool and cement retainer are run in a single trip. This system also allows squeeze cementing in underbalanced conditions. Jobs can be run with clear fluids instead of drilling fluids, which can create costly disposal problems. The gun’s design incorporates a pressure-activated, shear-sleeve firing head. The system can be configured to isolate the rathole from firing pressure when required.

What materials are used in the gun’s construction?

The gun and firing head are made entirely of aluminum, which is very easy to drill.

What cement retainer is used?

The system includes Halliburton’s field-proven cement retainer EZ Drill® SVB Packer (EZSVB).

8-6 Appendix

AutoLatch™ Gun Connector FAQs

Are special BOPs required for the AutoLatch™ Connector?

No. The only requirement is that the spacing between the BOP rams fit the linear dimensions of the connector. If required, spacer spools can be inserted between the BOP rams.

Does the AutoLatch Connector need to be centralized in the BOP stack?

Yes. The BOP rams must close equally on the seal area of the stinger in order for the retrieving tool to properly latch to the top of the stinger. The running tool must also be centralized in the BOP stack.

What section lengths can be run?

It depends on the equipment available to build the riser section. We have deployed single 22-ft gun sections and sections of up to three 22-ft guns.

Can pressure-actuated firing heads be used or should only ball drop firing heads be used?

Either type firing head can be used. However, extreme care must be taken when running pressure-actuated firing heads. Well pressures and well return must be constantly monitored.

In an emergency, can the BOP shear rams be closed on the gun?

No, never close the shear rams on guns. Even when the guns have been fired, it cannot be determined if all explosive materials have been detonated until the gun is out of the hole.

However, if the situation requires, the Christmas tree’s high shear ram can be closed.

How much right-hand torque can be applied to break out a gun section?

Maximum torque is limited by the guns to 6,000 ft/lb.

What if a gun section will not break out?

If the optional backup release sub is included in the string, rotating to the right will back off the sub. Then, an overshot can be run. Once it latches, and the connection is tested, the string is pulled up to the next seal sub in the seal-slip.

How is a gun broken out should the sealed initiator develop a leak?

A short-catch overshot and grapple is used. The procedure does require more time, but gun sections can continue to be retrieved under pressure.

What if multiple sealed initiators begin to leak?

Simply continue retrieving gun sections using the short-catch overshot.

What if the BOP leaks?

If the connection has not already been made and if the leak is not dramatic, connect with the short-catch overshot and lower the guns below the Christmas tree. Close and test the lower pipe ram, and then, repair the leaking ram.

If the leak is serious, contingency procedures are followed.

What inserts work best in the seal/slip rams with the ratchet gun connector?

Stewart-Stevenson inserts with straight slips work well.

Appendix 8-7

8-8 Appendix

Documents

Halliburton - Perforating Solutions