Hallibuton Well test manual

Table of ContentsWell Testing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .1-1Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-1 New Well Testing Technology . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2 Sharing Knowledge to Exceed Customer Expectations. . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-2 Doing the Right Thing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-4 Objectives . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1-5

Reservoir Solutions. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .2-1Reservoir Knowledge Center . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-1 Collaborative Well Testing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-1 Real-Time Reservoir Solutions (RTRS) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-2 Res 20/20 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-3 Well Test Analysis Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-4 Underbalanced ApplicationsReal-Time Reservoir Evaluation (RTRE) . . . . . . . . . . . . . 2-6 Examples of Downhole Solutions . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-8 Openhole Test Installation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-8 SmarTest System Installation. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-9 Cased Hole Test Installation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-10 Harsh Environment Test Installations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-10 Offshore Well Test Installation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-11 Deepwater/Floating Vessel Well Test Installation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-11 Land/Jack-up Well Test Installation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-12 FasTest System Installation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-12 Shoot and Pull Test Installation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-13 STPP-GH Single-Trip Perf/Pack System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2-13

Data Acquisition Services . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .3-1Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1 Pre-Job Planning . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1 Real-Time Operations . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-1 INSITE Anywhere Service . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-3 HalLink Satellite Systems. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-4 Surface Data Acquisition . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-5 SCAN 3 Data Acquisition System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-5 Emergency Shutdown (ESD) SystemFor Underbalanced Operations . . . . . . . . . . . . . 3-6 SCAN 3 Logger Module . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-6 Emergency Shutdown System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-7 PWD-M Electronic Memory Gauge and Gauge Carrier for Underbalanced Drilling Applications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-8 Downhole Data Acquisition. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-10 ATS Acoustic Telemetry System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-10 Instream Gauge Carrier . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-16 Electronic Shut-In Tool . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-17

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SG-15 Gauge Carrier . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-18 External Big Bore Gauge Carrier. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-19 DynaMem Electronic Memory Gauges. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-20 DynaMem Gas Lift Side-Pocket Mandrel Gauge. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-24 Halliburton Surface Readout System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-25 Reservoir Performance Monitoring . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-26 FastQ Multiphase Flow Meter System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3-26

Fluid Sampling and Analysis. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .4-1Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-1 Reservoir Fluid Sampling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2 Surface Sampling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-2 Bottomhole Sampling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-3 Reservoir Fluid Analysis. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-4 Research and Development Projects. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4-5

Test Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .5-1Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-1 Purpose of Well Tests. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-1 Pre-Job Planning . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-2 Metallurgy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-4 Cased Hole. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-7 String Examples . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-7 CHAMP IV Packer. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-8 RTTS Packer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-10 RTTS Safety Joint . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-12 Below Packer Hydraulic Safety Joint . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-14 Express Circulating Valve. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-16 FUL-FLO Hydraulic Circulating Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-18 Internal Pressure-Operated (IPO) Circulating Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-20 OMNI Circulating Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-22 RTTS Circulating Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-24 Rupture Disk (RD) Safety Circulating Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-26 VIPR Circulating Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-28 LPR-N Tester Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-30 Select Tester Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-32 Tubing String Testing (TST) Valve. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-34 Rupture Disk (RD) Tubing String Testing (TST) Valve. . . . . . . . . . . . . . . . . . . . . . . . . . 5-36 Rupture Disk (RD) Tubing String Testing (TST) Bypass Valve . . . . . . . . . . . . . . . . . . . 5-37 Rupture Disk (RD) Bypass Pressure Test Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-38 Accessory Tools. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-39 Slip Joints . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-39 Round Mandrel Slip Joint . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-40 BIG JOHN Hydraulic Jar. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-42 Drain Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-44 Rupture Disk (RD) FUL-FLO Sampler . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-45

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SIMBATubing-Mounted Single-Phase Fluid Sample Carrier . . . . . . . . . . . . . . . . . . . 5-46 Shock Absorber. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-48 MPV Pressure Test Bypass Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-50 Pressure-Responsive (PR) FAS-FIL Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-52 Pressure-Responsive (PR) Multi-Service Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-54 Super Safety Valve. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-56 Openhole . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-57 String Examples . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-57 Straddle Packer Pressure Equalizer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-58 Hollow Plug Impact Reversing Sub . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-59 Pump-Out Disk Reversing Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-60 HYDROSPRING Tester. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-62 LOC Bypass Valve. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-64 Multiple Closed-In Pressure (CIP) Sampler . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-65 Operating Diagram for Multiple Closed-In Pressure Sampler with Locked-Open Bypass Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-66 Extension Joint . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-67 Dual Closed-In Pressure (CIP) Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-68 Dual CIP Sampler. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-69 VR Safety Joint . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-70 Distributor Valve . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-71 Non-Rotating (NR) Expanding Shoe Wall Packer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-72 Internal Pressure Compensating (IPC) Expanding Shoe Wall Packer . . . . . . . . . . . . . . 5-73 Anchor Pipe Safety Joint . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-74 Flush Joint Anchor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-75 Side Wall Anchor . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 5-76

Advanced Well Testing . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .6-1Overview . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-1 Purpose of Well Tests. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-1 Pre-Job Planning . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-1 FasTest System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-2 FasTest System Vents . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-8 Topo Packer . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-10 SmarTest System . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-12 SmarTest Installation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6-13

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Introduction

Well TestingIntroductionOver a half century ago, Halliburton introduced drillstem testing (DST) to the oil industry, establishing the initial standard for well testing. These early well tests provided an understanding of reservoir productivity, fluid type, and near-wellbore boundaries. Over the years, well testing has evolved dramatically to provide greater reservoir information. Just as well testing has evolved, so has Halliburton. Today Halliburton provides well testing systems that collect bulk and pressure/volume/temperature (PVT) samples that when analyzed at the Westport fluids laboratory, provide input for completion design, production facility design, and establishment of refining properties. Well testing systems also allow for safe collection of data necessary to perform interpretations that determine productivity indicators such as permeability, skin, and initial reservoir pressure. Permeability is used to forecast cash flow. Skin enables prediction of expenditure needed to improve productivity. Initial reservoir pressure is one of the parameters needed to determine hydrocarbon is in place. Halliburton well testing systems can also be used to gather long term data, that when interpreted, establish reservoir structure such as the existence of heterogeneities, discontinuities, and connectivity. Halliburton continues its leadership in well testing by providing solutions that are safe and environmentally responsible. The broad range of Halliburton products and services provide fit-for-purpose well testing solutions that deliver dynamic reservoir information required by clients.

HAL14612

Well Testing Real-Time Operation

Introduction

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New Well Testing Technology New Well Testing Technology

HAL15013

Halliburton 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. Halliburton strives to be the leader in identifying, developing and commercializing new technology. Some of the more recent technological innovations described Real-Time Reservoir Solutions are listed below. in this catalog Underbalanced Applications l Real-Time Reservoir Solutions Collaborative Well Testing l Underbalanced Applications INSITE and INSITE Anywhere services l Collaborative Well Testing HalLink Satellite Systems and INSITE Anywhere services l INSITE l HalLink Satellite Systems ATS Acoustic Telemetry System l Flow Meter System FastQ Multiphase ATS Acoustic Telemetry System l Transmit and Receive Integrated Communications System (T.R.I.C.S.) Reservoir Fluid Sampling l FastQ Multiphase Flow Meter System FasTest System l Reservoir Fluid Sampling SIMBA - Tubing-Mounted Single-Phase Fluid Sample Carrier l FasTest System Topo Packer l SIMBA Single-Phase Fluid Sampler Carrier SmarTest System Topo Drilling Packer l

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Introduction

Sharing Knowledge to Exceed Customer ExpectationsWhile 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. Halliburtons extranet portal, www.myHalliburton.com or Intelligence CentralSM portal provides personalized, user friendly, web-based access to technical content, tools, and applications that allow crossfunctional teams to collaborate in a single, easy to access environment. The myHalliburton.com portals 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 myHalliburton.com portal 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

Introduction

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Doing the Right ThingPlanning with the Halliburton Performance Improvement Initiative Halliburton Management System (HMS) The Halliburton Management System is Halliburtons foundation for day-to-day risk management and was developed in the mid 1990s in response to a request from the organization to unify safety, environmental, and quality management systems. As such, HMS incorporates the requirements of ISO 9000 and 14000 into process documentation, outlines service delivery steps, and includes the risks and controls associated with individual tasks. In addition to outlining the steps involved in each process, HMS also details who is responsible for each task and what needs to be done to protect people, assets, and the environment. Documentation for each mainstay process is then incorporated into global process maps. These maps are adopted locally with modifications permitted only as long as the integrity of each standard is maintained. The seven top-level mainstay processes are standard worldwide for each Product Service Line (PSL) to deliver consistency. Developing solutionsArea PII TeamsS&H SQ E

Planning for superior Health, Safety, Environmental (HSE), and Service Quality performance using Halliburtons Performance Improvement Initiative (PII)PII is Halliburtons 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, and assessment of currently available tools, and the development of objectives and strategies for continuous global improvement.Executive PII TeamsSafety & Health Service Quality Environment

Region/Country PII TeamsS&H SQ E

Prepare resources Mobilize resources Perform services/deliver products Demobilize resources Complete reports and field tickets Review performance Correction, Prevention, and Improvement System (CPI) The Correction, Prevention, and Improvement system (CPI) is used as the main tool for the communication of improvement ideas, lessons learned, and process audit issues. Trends identified in CPI are used to help plan, prioritize, and coordinate corrective actions, maintenance requirements, and improvement initiatives. Process improvements are reflected as changes to best practices and are communicated through training and application within the organization. The CPI system helps to facilitate collection, analysis, and reporting of feedback on performance.

Focusing on Prevention PII 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 Halliburton works. Site surveys, hazard observation, and risk analysis help control dangerous conditions.HMS PROCESS DOCUMENT ATION RISK ASSESSMENT JSA HAZARD OBSER VATION SITE SUR VEY PREVENTION CPI IMPROVEMENT NEAR MISS INCIDENT INVESTIGATION W/ FEEDBACK ROOTCAUSE W/ FEEDBACK POST CORRECTION

AUDIT PROCESS

0 PRE/LEFTof ZERO INCIDENT FOCUS

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Introduction

Performance Monitoring and Continual Improvement Another feature of the CPI database is the End of Job Customer Survey (EJCS). This survey allows the monitoring of on-site activities and performance with customers. By engaging customers (or their representative) on location, Halliburton representatives can immediately respond to issues of concern or dissatisfaction. Halliburton Business Development Representatives, Account Representatives, Operations Management, and Quality Management monitor the performance and work both internally and with their customer to improve performance. Records of EJCS are entered into the CPI database and can be queried for production of summary reports. In addition to the EJCS, the CPI database also maintains Key Performance Indicators (KPIs). After completing a customer job, a Halliburton service delivery employee creates a record of KPIs for that job. These indicators differ by Product Service Line (PSL) but generally are used to indicate key metrics relative to job performance. Most of the KPIs include a designation of whether or not there was a failure associated with the job. The KPIs are captured in a database, and reports summarizing KPI statistics are generated across several dimensions including customer, PSL, geography, service type, etc. The KPI process allows reliability studies to be performed in order to further increase service quality and field reliability figures.

Recognition At the end of each year, the executive teams evaluate progress to plan and award regions/countries with the PII Presidents Award for exemplary accomplishment. Results Since 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 HSE values, and injury rates have been reduced by over 50%.4.5 4 3.5 3 2.5 2 1.5 1 0.5 0 1995 1996 1997 1998 1999 2000 2001 2002 2003

Halliburton Historical Recordable Incident Rates2.5

ObjectivesService 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 environmental inventory Manage chemicals

2

1.5

1

0.5

0 1995 1996 1997 1998 1999 2000 2001 2002 2003

Halliburton Historical Lost Time Incident Rates

Introduction

1-5

1-6

Introduction

Reservoir Solutions

Reservoir SolutionsReservoir Knowledge CenterCollaborative Well TestingCollaborative well testing (CWT) is a process where Halliburton plans, monitors, and analyzes with clients a well test in real time without traveling to the well site. This process includes using project leaders, the myHalliburton.com collaboration portal, Real-Time Operations (RTO), and Real-Time Reservoir Solutions (RTRS). CWT improves safety, communication, service quality, and profitability for clients. Planning When test planning begins, a project leader is assigned to work in the client's office. Project leaders attend planning meetings and work with the client to determine the test objectives. The test objectives along with the reservoir information are used to specify required equipment and the well testing method. The project leader performs the engineering calculations, generates the equipment diagrams, and writes the operational and contingency procedures. A test design determines the duration of the flow periods and reservoir response. To ensure that work is conducted in a professional, safe, and effective manner, Halliburton utilizes the Halliburton Management System for process documentation, outline of service delivery steps, and documentation of the risks and controls associated with individual tasks. A job safety analysis (JSA) is performed to ensure safe testing. During planning, a private community is set up in the myHalliburton portal. Documentation related to the testing is stored in the community, including planning procedures, well diagrams, tool diagrams, process and installation diagram (P& ID) drawings, hydrate curves, test design program, inflow curves, JSA, and Halliburton Management System (HMS) documents. Meetings, equipment loadout, personnel on location, and test startup can be scheduled using the community calendar. Using the task manager feature, project leaders can assign tasks to community members. When using real-time operations, a link to the INSITE Anywhere website can also be included. Before sending the equipment to location, a Halliburton job coordinator travels to the well site to meet with the client and coordinate mobilization of equipment and personnel. During this visit, the job coordinator discusses with the rig crew the test procedure, equipment layout, and personnel role, and sends in a request for RTO.

Collaborative Well Testing

Reservoir Solutions

2-1

Testing During testing, data is transmitted in real time and displayed in the INSITE Anywhere system so collaboration between client staff and Halliburton operations and technology experts can occur during testing. RTO offers several improvements: Safety. Available well test data is delivered on location via the Internet to the team members. Communication. Team members receive the same data at the same time. Time management. The asset team is only required to log on to the protected website during actual testing. Log on can occur anywhere the Internet is available.

(the real-time version of Landmark's WELLCAT) takes the distributed temperature, along with flow rates and pressures, and calculates tubing movement and tubing/casing loads. The iWatch software updates the models as well parameters change. Example 1 HES performed a drillstem test in deepwater Malaysia for a large independent operator. A computerized network system acquired the surface data and the ATS acoustic telemetry system acquired the bottomhole data. Both systems streamed into the INSITE system, which transmitted data from the rig to the office in Malaysia via a third-party satellite system. In the office, the bottomhole pressure data was ported into Saphir where the Halliburton reservoir engineer performed a real-time pressure transient analysis. This real-time reservoir solution saved three days of rig time resulting in huge savings for the client. Example 2 Halliburton performed a flow assurance and post completion test on a deepwater well in the Gulf of Mexico for a large independent operator. Surface data along with third party downhole permanent gauge data was brought into the INSITE system. It was then transmitted through the Halliburton self-stabilizing satellite terminal to the Houston Real-Time Operations Center. In Houston, the Halliburton reservoir engineer performed real-time pressure transient analysis and collaborated with the operator's reservoir engineer. The buildup was shortened by four hours, saving $40,000 rig time.

Real-Time Reservoir Solutions (RTRS)Real-time reservoir solutions allow clients to quantitatively describe the reservoir while directing the procedure to achieve all of the test objectives. The INSITE data management system integrates test data from all of the acquisition systems and routes it to diagnostic software including pressure transient analysis software, real-time calculators, and completion integrity software. The pressure transient analysis software calculates the effective permeability, skin, rate dependent skin, extrapolated pressure, productivity index, and reservoir geometry. Parameters such as drawdown, productivity index, water yield, and gradients are calculated with the real-time calculators and are used to determine completion efficiency and well cleanup. Halliburton's iWatch software

HAL6735

One of the many ways Halliburton achieves its test objectives is through Real-Time Reservoir Solutions (RTRS).

2-2

Reservoir Solutions

Res 20/20Halliburton offers complete reservoir services worldwide, incorporating the most advanced technology to help obtain optimum results from reservoir development. To ensure successful testing, Halliburton provides the following to enable faster, more informed decisions about well conditions and production, regardless of location. Project leader to provide job design, coordinate equipment mobilization, provide well site technical support, and post job analysis to customers Consultants working in-house, at the client office, or on well location and providing perforating consulting, production optimization, well testing, and fluids management Perforation design using reservoir and well information to optimize the perforations Software that calculates the dynamic parameters associated with perforating including direction of shock wave, intensity, amount of gun movement, and effect on hardware such as bridge plugs and packers In-house well test consultant (Halliburton engineer) to work with the client to determine test objectives, design the well test, supervise test, and complete the end of well report On-location well test consultant (Halliburton engineer) to oversee equipment rig up, host pre-job safety meeting, host daily safety meetings, lead testing operation, ensure test objectives are met, and serve as primary customer contact on location Process and installation diagram (P&ID) created for surface test equipment, underbalanced drilling surface equipment, or early production system equipment Hydrate prediction that includes well information, reservoir information, water depth, pressure/volume/ temperature (PVT) of hydrocarbons, and inhibitor properties used to develop hydrate curves for varying amounts of free water and inhibitor pumped Completion design that includes wellbore information, reservoir information, log data, core data, fluid compatibility tests, drilling records, and PVT of hydrocarbons used to design optimized completion Project manager for underbalanced applications responsible for the overall direction of all drilling, drilling related, and support service operations conducted by the Project Team Heat radiation calculations that use maximum gas rate expected to flare, maximum condensate rate expected to burn, hydrocarbon properties, and burner boom length to calculate heat at several distances from a heat source under various wind conditions FasTest toolstring design that includes placement of gauges and samplers, volume of chamber, type of tubing conveyed perforating firing head, length of blank gun, and amount of underbalance applied to the reservoir FasTest reservoir performance test design that includes pressure response, chamber volume, amount of underbalance applied to the reservoir, and duration of the test needed to successfully analyze test data Injection/falloff test design that calculates pressure response, injection rate, duration of injection, and duration of falloff needed to meet all test objectives and successfully analyze test data Tubing movement calculations that calculate pressure and temperature profiles to determine pipe movement as well as calculate stress, load on packer, collapse, burst, and chance of buckling Design of service that includes design of the drillstem test, tubing conveyed perforating, service tools, underbalanced drilling, reservoir performance monitoring, data acquisition, and production application

Reservoir Solutions

2-3

Well Test Analysis OverviewA well test analysis report can save time and money by identifying opportunities to improve well performance. Halliburton engineers, drawing on their extensive experience, generate analysis reports using the most advanced pressure-transient analysis and well evaluation methods available. Well test and completion data can help get a more accurate reservoir description. In addition, reports often include recommended techniques for well performance improvement. After the compatibilities of the fluid property, rate, and pressure data are verified, well test analysis is performed using advanced and sophisticated reservoir models. The completions can be horizontal, deviated, or vertical wellbores. The reservoir flow can be through dual-porosity, composite, layered, or homogeneous rocks. Results reported in a Halliburton Well Test and Completions Analysis Report take into account changing well storage, limited wellbore entry, tidal, and turbulent flow effects. Various well test analyses provide calculations for initial reservoir pressure (Pi), permeability thickness (kh), and skin (S). Additionally, wellbore perforated length (Hw), distance of horizontal wellbore to bottom of formation (Zw), and ratio of vertical to radial permeability (kz/kr) are calculated for horizontal wells. The dual-porosity flow model provides values for interporosity flow parameter (), the fraction of the pore volume occupied by the fissures to the total interconnected pore volume, and storativity ratio (), the ability of the matrix to flow into the fissure network. Stimulated wells are characterized by the fracture half-length (Xf) and conductivity (fc). Distances to boundaries and the boundary type (no-flow, constant pressure, or leaky) can be provided with most models. Well test analysis includes: Type curve analysis Conventional analysis Non-linear regression Multi layered analysis Closed-chamber DST/FasTest system Production analysis Completion design/optimization reports Reservoir/well performance projections

HAL4971

Application of Well Test Analysis

Features and Benefits Experienced reservoir engineer available for questions Analysis report Follow-up briefing on analysis results and recommendations More consistent reservoir/wellbore description using all the data Well improvement recommendations using proven technologies Complete report that can be used to convince others of future recommendations Money saving ideas More time to concentrate on other projects Enhanced reservoir and completion description from the advanced and sophisticated reservoir models Analysis performed in batch or real time Recommendations for well improvement which consider the total system (reservoir, completion, and surface equipment) Fast turnaround at a reasonable cost to free up valuable engineering time

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Reservoir Solutions

Well test analysis service differentiating factors include:BHP [psia]

Service performed by experienced reservoir engineers Easy to use report Advanced well/reservoir models Real-time analysis capabilities using a secured website that can be accessed using your computer anytime or anywhere Some of the well test data analyzed includes: Closed chamber or surge testthis type of data can be collected using the FasTest system Slug, shoot and pull, or drillstem test Formation test Vertical well tests (radial or fractured) Horizontal well test Multi-rate well test Bounded reservoir test Permanent gauge data test

5500Skin

14 12 10 8 6 4 2

Analysis Results Prod Index = 4.95 Mscf/D - psi Storage Constant = 0.00509 STB/psi True Skin = 1.96 True Delta P Skin = 71 psi Turb Skin = 4.58 Turb Delta P Skin = 165 psi Turb Factor = 0.00131 1/Mscf/D Initial Pressure = 6000 psia kh = 141 md-ft k = 4.7 md

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Skin vs. Rate

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HAL7687

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History plot (Pressure [psia], Gas Rate [Mscf/D] vs Time [hr])

Multi-Rate Test5000

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Pbar

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9000

HAL7688

Gas Rate vs Time0 1000 2000 3000 4000 5000 6000

(Pressure [psia], Gas Rate [Mscf/D] vs Time [hr])

History of Plot Pressure and Rate Showing Analysis Model Match

3,000 ft 3,000 ft 2,500 ft

HAL7755

2,000 ft

Reservoir Shape

Reservoir Solutions

2-5

Underbalanced ApplicationsReal-Time Reservoir Evaluation (RTRE)The Halliburton underbalanced applications (UBA) real-time reservoir evaluation (RTRE) is a comprehensive engineering process that integrates and sequences surface and subsurface data obtained during underbalanced drilling. This data is evaluated to characterize the reservoir and yield valuable production data such as productivity index and permeability. The process begins with preliminary analysis of offset well data and design of testing procedures to maximize the reservoir information obtained during the drilling process. The Halliburton INSITE system of data acquisition and data management brings the data to one platform after which a unique reservoir model is used to analyze the pressure and rate data to determine reservoir productivity. One of the components of this reservoir model, TimeSplice, is initially used to transpose and correct the surface rate data to the bottomhole, taking into account the injection and production lag times. The bottomhole pressure corresponding to each traversed layer in conjunction with other input data is then used by the analytical transient reservoir model to calculate the rate from each productive zone. To characterize the reservoir even more accurately, the numerical reservoir simulator component can be used. Reservoir engineers and geologists work together to interpret the results from the predictions and advise the on-site engineers of any additional testing required for further reservoir characterization or modifications to drilling plans. This testing while drilling methodology yields important reservoir information that in many cases greatly changes the reservoir knowledge in a field. Reservoirs which previously did not merit testing are automatically tested during the drilling phase providing reservoir knowledge to the asset manager. The Halliburton RTRE is composed of tools that allow this data to be analyzed accurately and rapidly by amalgamating several advanced techniques and methodologies. There have been cases where zones previously not seen or not deemed productive with conventional drilling were found to contain economic reserves to justify completion. Figure 1 illustrates where previously deemed non-commercial pays (indicated by the top yellow arrows) make significant contributions to total production rates when not exposed to the damage of overbalanced drilling. The reservoir evaluation capability of Halliburton UBA maximizes the discrete characterization of these intervals allowing for full exploitation of the reservoir.

ROP Avg fph1000 500

MD Deep Phase Res in 02 20 ohm-m ft Underbalanced Pressure Medium Phase Res Bulk Density psig 0 20 1.65 2.65 1000 ohm-m 0 1.50 02 g/cc Productivity Index Formation Permeability Shallow Phase Res Well Flow Rate md STB/psi ohm-m 20 02 STB/d 0 1000 50 1000 07050

7150

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Figure 1: Output of Reservoir Evaluation from UBA Information

2-6

Reservoir Solutions

For the asset manager, even more valuable information can be gained about the reservoir. In many conventional underbalanced operations without this reservoir focus, a pay interval is drilled mostly underbalanced but often with some overbalance occurrences. The result of this temporary overbalance is often overlooked and never quantified. Using the RTRE with its detailed data acquisition and analysis ability, many overbalanced events are now quantifiable, leading to very accurate information on the cost of failing to achieve true continuous underbalanced drilling. Figure 2 is a simulation extracted from a composite of field cases which were seen with the UBA-RTRE. As pay is intersected in an underbalanced environment, the RTRE kicks in, resulting in an accurate quantified reservoir characterization. As sometimes happens, an unplanned pressure event throws the system into overbalance, even for a relatively short period of time. After underbalanced conditions are returned, the damage to the reservoir can be expertly determined. In Damage Rate 1, a five-fold reduction in rate is determined. After an extensive effort to blow out the damage with greater drawdown pressures, the Damage Rate 2 is seen to be 2.5 fold. The most significant observation is that for this case, the damaged formation never cleans up to original rates over the observed period. The information from this qualified result is modeled by the RTRE and the resulting loss of productivity is quantified to an accurate value, giving the operator an exact evaluation of the lost production due to overbalance. In the typical well seen by Halliburton UBA, the loss of production over the life of the well greatly exceeds the cost of implementing the RTRE in conjunction with sound project management and engineering processes required to prevent these unplanned overpressure events.

Underbalanced Application

The first approach was to synchronize the surface measured injection and production rates to bottomhole, so that a representative sandface rate for each layer could be determined. Secondly, the nature of reservoir pressure transient testing had to be modified to account for the dynamics of having an ever changing reservoir height as the bit progresses through the pay. This meant that a moving boundary condition problem had to be solved. Once this solution was implemented, it was verified against more conventional industry pressure transient analysis models (for the simplest case of a constant wellbore length) and against numerical simulators (for increasing well length), giving results within a 5% tolerance. The broader implications of this approach may mean better reservoir characterization in less time than the industry standard wireline-based evaluation, especially when coupled with some basic logging while drilling tools.

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Figure 2: Simulated Underbalanced Job Chart with Overbalanced Event (composite of field cases)

Reservoir Solutions

Gas Rate, (mscfd)

Pressure, (psi)

2-7

Examples of Downhole SolutionsThis section provides examples of test installations for openhole, SmarTest system, cased hole, harsh environment, offshore, deepwater/floating vessel, land/jack-up, FasTest system, shoot and pull tools, and STPP-GH single-trip perf/pack system.

Openhole Test InstallationBelow is an example of an openhole single packer test, openhole straddle packer test, and hookwall packer test.Drill Collar Impact Reverse Sub (Optional) Handling Sub and Choke Assembly Dual Closed-In Pressure Valve HYDROSPRING Tester

Drill Collar Impact Reverse Sub (Optional) Drill Collar Handling Sub and Choke Assembly Drill Collar Dual Closed In Pressure Valve

Tubing Impact Reverse Sub (Optional) Tubing Handling Sub and Choke Assembly Dual Closed-In Pressure Valve Hydrostatic Tester

Pressure Recorder Hydraulic Jar

HYDROSPRING Tester

VR Safety Joint Upper Body Pressure Equalizer Pressure Equalizer Ports

Pressure Recorder

Hydraulic Jar VR Safety Joint Hookwall Packer

Pressure Recorder

Expanding Shoe Packer Assembly

Hydraulic JarFlush Joint Anchor

VR Safety JointPressure Recorder (Blanked Off)

Collar

Expanding Shoe Packer Assembly

Expanding Shoe Packer Assembly AdapterHAL14296

Perforated Tail Pipe

Flush Joint Anchor

Flush Joint Anchor Anchor Shoe

HAL14302

Pressure Recorder (Blanked Off) Thread ProtectorHookwall Packer Test

HAL14295

Pressure Recorder (Blanked Off)

Openhole Straddle Packer Test

Openhole Single Packer Test

2-8

Reservoir Solutions

SmarTest System InstallationDrill Pipe ATS Big Bore Transceiver Gauge Carrier Drill Pipe ATS Repeater Drill Pipe Drill Collar VR Safety Joint Upper Sub Equalizing TubeRD TST Valve

Large Volume Sampler

Jar

Internal Gauge Carrier Telemetry Actuated Circulating Valve Drain Valve Pig Catcher 7-in. Internal Flush Tubing

Upper NR Packer Perforated Anchor Pipe

Lower NR Packer Lower Sub Equalizing Tube Gauge Carrier

Pig Launcher

IPO Circulating Valve

Drill Collars

ATS Transmitter

Junk Chamber Access Valve Dump Chamber w/Air Junk Chamber Drain ValveHAL15163

Telemetry Actuated Tester Valve FasTest Sampler Carrier w/Fluid ID Tool FasTest Sampler Carrier

Drill Collars Blank Off Shoe Joint

SmarTest System Installation

Reservoir Solutions

2-9

Cased Hole Test InstallationThe figure below shows an example of a typical cased hole drillstem testing system.Retainer Valve

Harsh Environment Test InstallationsBelow is an example of a harsh environment (High Pressure/ High Temperature, H2S) well test installation.

Retainer Valve

Subsea Test TreeSubsea Test Tree

Slick Joint Fluted Hanger Tubing Slip Joints Radioactive Tag Sub RD Safety Circulating Valve Drill Collars Drain Valve APR (OMNI, Express) Circulating Valve Drill Collars Drain Valve APR (LPR-N, Select Tester) Tester Valve Sampler Gauge Carrier BIG JOHN Jars RTTS Safety Joint CHAMP IV Packer Below Packer Safety Joint Vertical Shock Absorber Radial Shock Absorber Balanced Isolation Tool Pup Joints Mechanical Firing HeadHAL15211

Slick Joint Fluted Hanger

RD Safety Circulating Valve APR (OMNI, Express) Valve Drain Valve APR (LPR-N, Select Tester ) Tester Valve

Drain Valve Gauge Carrier Sampler Carrier(s)

MPV Valve Permanent Packer Crossover

VannGun Assembly RDX, HMX, or PYX Charges (DD or BH)HAL14490

Mechanical Firing Head VannGun Assembly

Cased Hole Installation

High Pressure/High Temperature Test Installation

2-10

Reservoir Solutions

Offshore Well Test InstallationHalliburton offshore well testing solutions offer unmatched testing experience. Optimized testing configurations and procedures tailored to well conditions, faster, more accurate formation test data, reduced rig time, as well as real-time monitoring and on-site engineering help meet well test objectives. Below is an example of an offshore well test installation.

Deepwater/Floating Vessel Well Test InstallationThis figure illustrates an installation used with deepwater floating vessels.

Retainer Valve

Retainer Valve Subsea Test Tree Slick Joint Fluted Hanger Tubing Slip Joints Drill Collars RD Safety Circulating Valve Drill Collars Drain Valve APR (OMNI, Express) Circulating Valve Drill Collars Drain Valve APR (LPR-N, Select Tester) Tester Valve Sampler Gauge Carrier BIG JOHN Jars RTTS Safety Joint CHAMP IV Packer Below Packer Safety Joint Vertical Shock Absorber Radial Shock Absorber Balanced Isolation Tool Pup Joints Mechanical Firing HeadHAL14293

Subsea Test Tree

Fluted Hanger

Premium Tubing

RD Safety Circulating Valve Drill Collars Drain Valve APR (OMNI, Express) Circulating ValveAPR (LPR-N, Select Tester ) Tester Valve

Sampler Gauge CarrierBIG JOHN Jars RTTS Safety Joint CHAMP IV Packer Vertical Shock Absorber Radial Shock Absorber Balanced Isolation Tool

VannGun Assembly RDX, HMX, or PYX Charges (DD or BH)

Offshore Well Test InstallationHAL14485

Pup Joints Mechanical Firing HeadVannGun Assembly RDX, HMX, or PYX Charges (DD or BH)

Deepwater/Floating Vessel Well Test Installation

Reservoir Solutions

2-11

Land/Jack-up Well Test Installation

FasTest System Installation

Radioactive Tag Sub

RD or IPO Circulating Valve Super Safety Valve ATS Transmitter Premium Tubing RD Safety Circulating Valve Drill Collars Drain Valve APR (OMNI, Express) Circulating Valve Drill Collars Drain Valve APR (LPR-N, Select Tester) Tester Valve Sampler Gauge Carrier BIG JOHN Jars RTTS Safety Joint CHAMP IV Packer RTTS Safety Joint Time-Delay Firing Head Vertical Shock Absorber Radial Shock Absorber Balanced Isolation Tool Pup Joints Mechanical Firing Head VannGun AssemblyHAL14488

Select Tester Valve Drain Valve PVT Sampler Carrier Gauge Carrier

OMNI Circulating Valve Jars Safety Joint CHAMP IV Packer

Below Packer Safety Joint Fill Disk Assembly

VannGun Assembly Time-Delay Firing HeadHAL15153

Vented Closure

RDX, HMX, or PYX Charges (DD or BH)

Land/Jack-up Well Test Installation

FasTest System Installation

2-12

Reservoir Solutions

Shoot and Pull Test InstallationTubing Radioactive Sub Tubing IPO Circulating Valve Tubing Multi Service Valve OMNI Circulating Valve Tubing Gauge Carrier Tubing Jars RTTS Safety Joint APF-C Upper Pressure Transfer Sub CHAMP IV Packer APF-C Lower Pressure Transfer Sub Tubing Below Packer Safety Joint Tubing Fill Disk Assembly TDF APF-C Firing Head VannGun AssemblyHAL14489

STPP-GH Single-Trip Perf/Pack SystemThe STPP-GH single-trip perf/pack system provides costeffective, 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.

CHAMP IV Packer

Closing Sleeve Assembly

Blank Assembly

VBA FracPac Packer

Lower Sump Packer

Closing Sleeve Blank Screen

Hydraulic Release

VannGun Assembly

Shoot and Pull Test Installation

Auto Release Gun HangerHAL8829

Lower Sump Packer

STPP-GH Single-Trip Perf/Pack System

Reservoir Solutions

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Reservoir Solutions

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Data Acquisition Services

Data Acquisition ServicesOverviewData acquisition is one of the most important objectives of well testing. While the equipment used to perform a well test has improved technologically over the years, the need to acquire data remains the same. In order to consistently acquire well test data, the system must be reliable in operation, accurate in measurement, and provide information that is easily accessible to customers. Halliburton has worked continuously to develop its data acquisition portfolio to ensure reliability, accuracy, and easy access to information as it is being measured. Halliburton offers memory gauges, surface readout tools, and surface measuring equipment that will not only ensure that the data is secured, but also make the data available to other locations in real time. Halliburton does not stop at data collection. Information is also verified for accuracy before delivery to the client. In data acquisition, focus remains on the reservoir. At Halliburton, emphasis is on providing a high level of service to customers to meet their data acquisition needs. worldwide. Registered users also have access to all the products and service applications that myHalliburton.com provides. The portal provides practical, relevant resources and tools for data gathering, analysis, and real-time decision making for quick, effective service.

Real-Time Operations

HAL5015

Real-Time Operations Center

Pre-Job PlanningIn order to achieve success in field operations, pre-job planning must take on a central role in preparing equipment, personnel, and processes for job execution. The Halliburton Management System (HMS) serves as a pre-job planning and execution guide to ensure that work is conducted in a professional, safe, and effective manner. All equipment goes through a calibration process before going to the wellsite to ensure accuracy of measurement and availability of spare parts that are provided for any contingency. Check sheets are provided to guide personnel through required checks and are verifiable by the customer as required. Another important aspect of pre-job planning includes use of the myHalliburton.com portal which allows users to set up a collaboration community for sharing documents, posting questions, and managing tasks and calendars with registered team members and key Halliburton personnel

Todays competitive environment demands quick decisions. With Real-Time Operations (RTO), Halliburton is optimizing resources, reducing risks, reducing the time required to carry out operations, and maximizing well testing budgets. Using powerful HalLink satellite communications technology to bridge the distance between people and data, Real-Time Operations brings well test data directly to the experts, enabling Halliburton and the client to monitor and analyze a well test in real time without traveling to the wellsite. In addition to providing real-time access to data collected at the wellsite, the satellite communications system allows direct access to the Halliburton technical information network, direct voice access, and e-mail access from the wellsite. This means not only faster communication of vital information from the wellsite to support personnel, but also faster solutions for unplanned events.


3-1

The Halliburton surface readout (SRO) system provides a reliable method of receiving real-time downhole pressure and temperature data for early retrieval of data for analysis and decision making. This electric wireline-conveyed system is capable of transmitting data across Halliburton annulusoperated downhole tester valves in drillstem testing (DST) applications, or can be hung off on wireline in bottomhole pressure survey applications. The SRO system uses an extremely rugged sapphire gauge that also stores data in memory mode. The data sample rate can be adjusted throughout the test without the need to physically retrieve the gauge.HAL12254

INSITE Anywhere Drill View

To facilitate real-time decision making during well testing, data acquisition products were integrated with the field-proven INtegrated System for Information Technology and Engineering (INSITE) data management system. The INSITE system provides networked wellsite information that allows integration of well information for real-time analysis at the wellsite, at the Real-Time Operations Center, or in the clients office. The INSITE Anywhere service provides customized access to well data through an Internet connection without the need for complete installation of the INSITE system. As long as the client has access to the Internet and use of a web browser, well test data is as close as the nearest personal computer. The ATS acoustic telemetry system surface readout system is designed for drillstem testing-type applications on land and offshore. Unlike conventional surface readout systems that require complicated equipment or procedures to deploy, the ATS system uses acoustic energy to transmit real-time data to the surface. Access to accurate real-time data allows for flexible, well-timed decisions to reduce the cost of operations and enhance the economical value of the reservoir. With the ATS system, wireline intervention during well testing is greatly reduced or not required at all, significantly reducing risks involved with these operations.

Halliburtons SCAN 3 surface computerized acquisition network combines the most up-to-date electronic hardware and data gathering software for unsurpassed performance during well test operations. The SCAN 3 system measures, records, displays, reports, and analyzes well test information. Powerful system software uses this data to calculate well test parameters, such as flow and volume, and produces an accurate, real-time log of the application environment. Data is displayed on one of the selectable screen schematics and simultaneously printed and stored to disk. Historical and real-time data can be accessed, displayed, and evaluated at any time during the test. For underbalanced drilling operations, an automatic emergency shutdown system is available to ensure complete system reliability and safety during the surface injection and separation process. The overall flexibility of the system allows it to be used in a variety of situations.

HAL9210

Application of INSITE Database

3-2


INSITE Anywhere ServiceINSITE Anywhere service is a next-generation, web-based data delivery system that provides the flexibility of the industrys most robust database structure without the need to install special software. Using advanced satellite communications technology or any other network, the INSITE Anywhere service moves data from the logging tools onto a secured web site, for viewing in real time. When an unplanned event arises, the INSITE Anywhere web delivery system provides needed facts to command the situation. Solutions will be based on complete up-to-theminute information, and operators can participate in multiple wellsite operations from one location. With all the travel time saved, capabilities are stretched further, making the most of company resources. Features and Benefits View and print logging and tester data in real-time from any personal computer Access offset well data from nearby wells Download logging data, answer products, and more Configure display to individual preference by manipulating logging or test data View and print numerous display types including: log plots, pressure tests and samples, streaming downhole video, cross-plots, MRILab results, as well as efficient gauges, LEDs, and other indicators Expand personnel capabilities Speed decision-making Participate in multiple operations Optimize logging passes Deploy expertise and resources more efficiently Save travel expenses Avoid travel risk No special hardware or software required Requirements for Service Internet or intranet access Standard web browsers User name, password, and URLHAL11244

Security protections of the HalLink communications network or any other secure networkINSITE Anywhere Technology


3-3

HalLink Satellite SystemsHalLink satellite systems offer three systems: land (tripod), skid (compensating), and vessel (permanent). HalLink systems allow transmission of data and video at high speeds through a secure network supporting all Halliburton Real-Time Operations. With last mile connectivity to the location, real-time support and decisions can be made more easily. Features and Benefits Fully scalable to client needs, simple point-to-point network through full mesh (point-to-many) Deployment expandable per client needs Flexible, enabling the system to be part of the Halliburton or client network Two phone lines for operational support Improved reliability for wellsite connectivity Bandwidth scalable to local/client needs Services enabled by HalLink INSITE Anywhere service Collaborative formation evaluation and reservoir monitoring Real-time monitor and control Video conferencingHAL8061

Immediate data transfer

HalLink Satellite System

3-4


Surface Data AcquisitionSCAN 3 Data Acquisition SystemThe Halliburton SCAN 3 surface computerized acquisition network combines the most up-to-date electronic data gathering hardware and software to ensure complete system reliability during well testing and cleanup operations. The system is designed primarily for underbalanced drilling and well testing applications. However, its flexibility allows for use in a variety of situations. The SCAN 3 system is composed of three main component parts: Server (PC) with resident software Logger modules with 120 channel capability Emergency shutdown system module (for underbalanced drilling applications) Hardware All inputs are routed via the cabling system through the logger module, where analog to digital conversion takes place, to the server PC via a RS232 connection. Each logger module has a standard 19-in. rack-mount enclosure. All transducer inputs/outputs have safety barriers between them and the logger module, rendering the cable system intrinsically safe in the process environment. Data editing, zooming, automatic and manual sequence of events logging, alarm setting, channel resetting, and dampening are all available from the software suite. The system also allows real-time importing of data from other sources, such as surface readout gauges and other miscellaneous surface measurements. Local area networking (LAN) and wide area networking (WAN) are within the system's capabilities. Utilizing TCP/IP protocols and the INSITE Anywhere system, real-time data can be shared on location, at a remote office, the Halliburton RTO center, and via the internet. Software The main server functions as the platform for communication between the software and the firmware contained within the logger, receiving and transmitting data as controlled by the user. All data is stored on a disk at intervals defined by the operator. Simultaneously, parameters selected by the operator can be printed or viewed in real time. The report generator section of the software allows the user to select a standard report configuration or design a custom report. ASCII exports of all reports or the entire database are available from within the program suite. On-screen hot spots enable the user to navigate around the program suite with ease and drill down to channel set-ups, fluid property analysis, flow rate calculations, etc.

HAL6481

SCAN 3 Data Acquisition System


3-5

Emergency Shutdown (ESD) SystemFor Underbalanced OperationsThe emergency shutdown (ESD) system employs a programmable logic controller (PLC) to: read analog and discrete signals from the process plant. determine if the signal input is within the pre-set PLC safety limits. compare signal inputs to check integrity and calibration. produce an output to affect a fail-safe condition on the process plant. In addition to its data acquisition, reporting, and plotting capabilities, the SCAN 3 system offers the following features: Controls supervisory level safety via the output logic switch box (OLSB) Notifies all users on the LAN of emergency shutdowns and alarms Records a log of ESD events and alarms The SCAN 3 system and ESD software have been designed with overall system compatibility in an integrated package while maintaining data and safety integrity. All critical safety PLC settings are programmed via a separate terminal, which ensures that once this connection is removed, all safety parameters are permanently saved and tampering is prevented. Supervisory level alarms can be set from the SCAN 3 system to provide maximum application flexibility to preset analog input (cause) levels to initiate output (effect) sounders and beacons. Memory option for standalone, unattended operations Resident UART full duplex RS232 compatible; BAUD rate 9.6 to 115K Local LED display of RX, TX, and signal condition Software Features Zoom functionUnlimited highlighting to produce the finest detail Self-contained program suitePlots and reports viewed from within the application environment Full Microsoft Windows functionality including, Browse, Cascade, Tile, and Print Preview Auto-scaling of all plots; manual scaling override Calibration of all logged analog channels via 10-point matrix Screen application schematics with engineering data pasted to appropriate positions ASCII data outputsImportable into commercially available spreadsheet software Choice of engineering units Full icon-driven functionsComprehensive toolbar and status bar control Real-time plot analysisCursor graticule historical information selector Alarm level set pointsinternal and external Sequence of eventsEvent log filter for manual and automatic entry

SCAN 3 Logger ModuleFeatures 16-bit internal frequency counters 24-channel input per rack (120 channel max) Intrinsically safe barrier protection System microprocessor with internal high accuracy real-time clock 12 to 240 volt power supply Robust enclosurerack or stack Opto-isolated pulse counters for liquid flow measurement

3-6


Emergency Shutdown SystemFeatures Programmable Logic Controller (PLC) Input modules 32-channel pairs analog (64 total) Double processor redundant CPUs 5V DC power supplies (3 OFF) Power supply monitor Output modules (16) Key switch override for 32 paired inputs Input status LEDs typical input signals to the PLC Level sensors Pressure sensors Temperature sensors Fire detection loops Explosive gases Toxic gases Flame out detectors Short and open circuit detection Emergency shutdown push buttons Typical Output Signals from the PLC Control Devices Electric fluid transfer pumps Surface safety valves Subsurface safety valves Sounder and beacon skids Power supplies Deluge system Emergency lighting


HAL5430

3-7

PWD-M Electronic Memory Gauge and Gauge Carrier for Underbalanced Drilling ApplicationsThe Halliburton PWD-M electronic memory gauge has been specifically designed to withstand hostile drilling environments and allow for accurate annulus measurement of bottomhole pressure and temperature. The electronic memory gauge is internally shock-mounted and installed on a mandrel within the carrier housing, affording physical protection of the gauges during drilling applications. Applications Underbalanced drilling operations Well testing while drilling Any drilling operation where temperature and pressure recordings are required Features and Benefits Serves as an inexpensive alternative or backup to PWD service Serves as an alternative when the type of drilling medium prevents running PWD service Does not compromise bottomhole assembly design Can be placed anywhere in the drillstring Can be run at any angle of inclination Full borewireline compatible Make-up torque the same as the drillstring Can run multiple carriers in string to enhance wellbore modeling Can handle up to four memory gauges per carrier Operation Customized data sampling frequency for gauges available Simple computer programming for interfacing with gauges High accuracy and resolution

PWD-M Gauge Carrier

3-8

HAL11022


6.75-in. OD GaugeNominal OD in. (mm) 6.75 (171.45) Nominal ID in. (mm) 2.25 (57.15) Make-up Length in. (cm) 78.66 (199.79) Overall Length in. (cm) 83.03 (210.89) End Connections 4 1/2 in. API IF Max. Tensile Load lb (kg) 650,000 (294 840) Working Pressure psi (kPa) 5,000 (34 474) Burst Pressure psi (kPa) 5,000 (34 474) Collapse Pressure psi (kPa) 5,000 (34 474) Tool Weight lb (kg) 670 (303.9) Design Specification NACE MR0175 Number of Gauges 4

4.75-in. OD GaugeNominal OD in. (mm) 4.75 (120.65) Nominal ID in. (mm) 1.5 (38.1) Make-up Length in. (cm) 70.89 (180) Overall Length in. (cm) 74.76 (190) End Connections 3 1/2 in. API IF Max. Tensile Load lb (kg) 400,000 (181 440) Working Pressure psi (kPa) 5,000 (34 474) Burst Pressure psi (kPa) 5,000 (34 474) Collapse Pressure psi (kPa) 5,000 (34 474) Tool Weight lb (kg) 290 (131.54) Design Specification NACE MR0175 Number of Gauges 2

GaugeTransducer Type Pressure Range psi Pressure Accuracy 0.022% of full scale Pressure Resolution 0.0004% of full scale Pressure Drift Temperature Rating Sample Rate 1 sample / 10 seconds Data Set Contents Pressure/ Temperature/ Time Memory Capacity 260,000 standard, up to 1,000,000 OD in. (mm) 0.75 (19.05) Overall Length in. (cm) 16 (40.64)

Sapphire

0 to 15,000

< 3 psi/year

125C


3-9

Downhole Data AcquisitionATS Acoustic Telemetry SystemThe ATS acoustic telemetry system is a battery-powered surface readout (SRO) system, designed for drillstem testingtype applications on land rigs, offshore jack-up rigs, and floating rigs (deepwater). The ATS system distinguishes itself from conventional surface readout systems by sending data through the tubing wall using acoustic energy instead of wireline. Multiple sensors, equipped with Halliburton proprietary quartz crystal technology, provide accurate pressure and temperature monitoring downhole. Data acquired downhole is transmitted to the surface in real time. Wireline intervention is optional, for example, for carrying out diagnostics or retrieving historical data (i.e., data from memory). Applications Exploratory or developmental wells where real-time subsurface data during well testing operations is desired Features and Benefits Easy to Use: The ATS system does not require complicated equipment or procedures to deploy. Once the workstring is in place, the system uses acoustic energy to transmit real-time data to the surface where a nonintrusive receiver forwards the data to a computer for decoding, display, and evaluation purposes. Real-Time Decisions: The ATS system reduces the cost of operations and enhances the economical value of the reservoir through flexible access to critical and accurate real-time (or stored) data pertinent to the reservoir evaluation. This flexibility allows for well-timed decisions including early test termination and/or increased recovery of hydrocarbons through optimizing production enhancement treatments such as frac or acid. Reliability: The system incorporates a fit-for-purpose mechanical design and the latest digital microchip technology. It offers built-in redundancy through multiple autonomous subsystems, nonvolatile memory, and the option of wireline intervention as a contingency.HAL10940

Reduced Risk: Wireline intervention during well testing operations is greatly reduced or not required at all. This significantly reduces the operational and health, safety, and environment-related risks involved with these operations, such as the exposure of personnel to potentially hazardous wireline or rig-floor related operations. An additional advantage is the absence of wireline operations through subsea safety systems during deepwater operations.

Transceiver Large Bore Transceiver

Repeater Repeater

Transmitter Transmitter

Tester Valve Tester Valve

Acoustic Split Screen

3-10


Operation The system is mainly used in conjunction with 5-in. OD drillstem testing (DST) tools. The ATS system combines the functionality of conventional memory gauges with wireless surface readout capability. The downhole transmitter accommodates three quartz sensors. Each sensor stores up to 440,000 records in memory, allowing for a great deal of flexibility during testing operations. The total storage capacity of the transmitter is over 1.3 million data records. The rate at which data are stored in memory is independent of the real-time SRO rate. In real time, every two minutes, the transmitter sends previously acquired data called a packet to the repeater. The repeater then forwards the packet to the surface for decoding. A packet is one cluster of acoustically transmitted data. It contains 12 pressure, temperature, and time readings, each at a sample interval of 10 seconds. The system as a whole is capable of communicating acoustically in both directions, allowing the operator to send down additional commands or instructions. A variety of data can be acquired and transmitted including: pressure temperature a variety of commands and instructions system-related status information

For land and offshore jack-up rigs, a surface transceiver is clamped onto the tubing just above the rotary table on the rig floor. On floating vessels, subsea safety systems severely attenuate or prevent the acoustic signals from passing through. To allow communication between ATS and subsurface components during deepwater applications, a large bore transceiver is installed below the subsea tree. The maximum operational depth of the ATS system is approximately 12,000 ft (3650 m) MD, provided a repeater is added to the workstring and positioned at half the total depth of the system's transmitter. In deepwater applications, the water depth is added, as the large bore transceiver is located at the ocean floor.

Data Processing


HAL14439

time

ATS Acoustic Telemetry System

3-11

Components The ATS system consists of a number of surface and subsurface components. The subsurface components all have a 5.25-in. OD and 2.25-in. full bore ID and are compatible with the Halliburton DST tool suite. Components include the transmitter, the repeater, the surface transceiver (land and jack-up applications), or the large bore transceiver (deepwater applications), the latch and bypass assembly, wireline probe, and data processing unit. From the bottom to the top: The transmitter is the downhole component closest to the reservoir and is usually located above a tester valve. Its quartz sensors can be ported to the tubing or annulus as required. The transmitter is capable of transmitting and receiving wireless data to and from the surface over a distance of up to 6,000 ft (1825 m) MD. The repeater, positioned between the transmitter and transceiver, has a signal booster function. It receives and forwards acoustic signals in both directions and is required when the transmitter depth exceeds 6,000 ft (1825 m) MD. It extends the acoustic range of the system to a total depth of 12,000 ft (3650 m) MD.HAL6301

Acoustic Stack

Acoustic Stack

Batteries

Electronics

Batteries

Electronics

Pressure/Temperature Sensors

On/Off Switch

HAL6302

Transmitter

Repeater

3-12


The wireline probe is an optional device to retrieve historical data, optimize transmission frequencies, and perform system diagnostics. It requires standard monoconductor cable and uses a proven ratchet locking mechanism to secure the wireline assembly in dynamic conditions (e.g., flowing, pumping). The latch and bypass assembly has a twofold function. The latch sub secures the wireline probe during flowing or pumping by way of an Otis X nipple profile. The large ID (3 in.) of the flow extension sub prevents restricted flow in the tubing ID. The large bore transceiver is a power unit that allows for transmitted commands down the string to the ATS transmitter.

Electronics

Acoustic Stack

Bypass

Otis X ProfileCentralizer

Bypass

HAL6299

Wireline Probe


HAL6300

Latch and Bypass Assembly

3-13

The surface transceiver is a battery-operated, explosionproof, nonintrusive unit located at the rig floor. It is used during land or offshore jack-up testing operations. The transceiver interfaces reservoir-related data or a variety of commands and instructions between the data processing unit in a safe area and the subsurface ATS components. It is connected to the data processing unit via an intrinsic safe optical fiber serial link (RS232). The data processing unit is located in a safe area, such as a lab, and controls all ATS components from this central location. It accommodates all ATS associated surface electronics to interface with the subsurface components and decodes data for storage, display, and evaluation purposes.HAL10938

Surface Transceiver Unit

ATS Acoustic Telemetry SystemMethod of Operation Acoustic OD in. (cm) 5.25 (13.335) ID in. (cm) 2.25 (5.715) (full bore) Pressure (Working) psi (bar) 15,000 (1034) Maximum Temperature Rating F (C) 330 (165) Maximum Tensile Load lb (kg) 400,000 (181 440)

Depth (Acoustic Data to Surface) up to 12,000 ft-MD (3,650 m-MD)

Bidirectional Communication Yes (data up, commands down)

Wireline Interrogation Possible Yes (used as contingency)

Monitor Data Across a Tester Valve Yes

Position (Depth) of Probe Critical No (large window)

Secure Probe in Dynamic Conditions Yes (latch sub)

Data Type Provided Pressure/ Temperature/Time

3-14


SensorsMake Type Quantity Flexible Porting Yes (to tubing or annulus) Pressure Range (Calibrated) psi (bar) Pressure Resolution psi (bar) Better than 0.06 (0.002) at 1 sec; Better than 0.015 (0.001) at >1 sec Pressure Accuracy Temperature Resolution F (C) Temperature Accuracy F (C) 0.18 (0.1)

Halliburton

Quartz

3 ea

0 to 16,000 (1103)

0.03% FS

0.003 (0.002)

Data StorageData Storage (in Addition to Real-Time) Yes Data Capacity (Total of All Three Sensors) 1,320,000 records (440,000 ea) Data Sample Rate (Real-Time/Memory) 10 sec (real-time)/ 1 sec (memory) Independent Real-Time/Memory Sampling Rate Yes Data Retrieval (Historical) Yes (via probe) Selective Data Retrieval (Window) Yes (via probe) Battery Life 20 days

ApplicationsTest Types Drillstem Testing (DST) Well Testing Well Types Oil and Gas Well Locations Land, OffshoreShelf, and Deepwater Suitable Tubing Type PH-6, VAM, Hydrill (Premium Thread) Suitable Tubing Size in. (cm) 2 7/8 to 4 1/2 (7.303 to 11.43)

Additional FeaturesBuilt-in Redundancy Real-Time Data Analysis Local/Collaborative Data Monitoring Yes, using Halliburton RIGSITE or RIGSITE PLUS Services Remote/ Collaborative Data Monitoring Yes, using Halliburton INSITE Service Remote Data Monitoring via Internet

Memory Gauge (optional)

Yes

Yes, using Halliburton INSITE Anywhere Service


3-15

Instream Gauge CarrierInstream gauge carriers carry as many as four pressure or temperature gauges in the flow stream to monitor downhole conditions while maintaining a full opening through the tools. The carriers are designed to carry 1.25-in. (31.75-mm) diameter electronic or mechanical gauges. Recorders are suspended on the inside of the running case, which has cushioning devices to protect the gauges from shock. Features and Benefits Permits unrestricted flow through the tools Allows wireline operations to be run Facilitates a faster response to temperature changes

Instream Gauge Carrier

Instream Gauge CarrierNominal Tool Size in. 5.50 5.50 OD in. (cm) 5.50 (13.97) 5.50 (13.97) 5.75 (14.605) ID in. (cm) 2.25 (5.72) 2.25 (5.72) 2.25 (5.72) Thread Service Temperature* Connections F (C) 3 1/2 IF 3 7/8 CAS 450 (232) 450 (232) 450 (232) Length in. (cm) 93.23 (236.80) 93.57 (237.67) 93.57 (237.67) Tensile Rating** lb (kg) 285,000 (129 276) 285,000 (129 276) 229,000 (103 874) Working Pressure*** psi (bar) 10,000 (689) 10,000 (689) Burst 15,000 (1034) Collapse 13,500 (930) Burst 10,000 (689) Collapse 9,000 (620) Number of Gauges 4 4

5.75

3 7/8 CAS

HAL14109

4

8.00

8.00 (20.32)

3.65 (9.271)

5 1/4 CAS

450 (232)

163.68 (415.75)

980,000 (444 528)

4

Meets NACE-0175 175F (79C) standards for H2S service *Service temperature up to 450F (dressed with 600 series o-rings and PEEK back-up seals) **The values of tensile, burst, and collapse strength are calculated with new tool conditions, Lames formula for burst and collapse strength, and stress area calculations for tensile strength. ***Pressure rating is defined as differential pressure at the tool. (Differential pressure is the difference in pressure between the casing annulus tool ID.) These ratings are guidelines only. For more information, contact your local Halliburton representative. PEEK is a trademark of ICI Americas, Inc. Poly-Ether-Ether-Ketone.

3-16


Electronic Shut-In ToolThe Halliburton electronic downhole shut-in tool (EST) is an electronically controlled, hydraulically actuated tool that aids in the testing of production wells. Closing in the well downhole reduces or eliminates the effects of wellbore storage, providing better test data for well evaluation. The EST is set in the production tubing and runs on slickline in conjunction with electronic gauges and/or bottomhole samplers. Electronic Timer Operation The battery pack supplies power to the timer, which measures elapsed time using a highly accurate electronic timing circuit. The timer is preprogrammed on the surface, prior to running in the well. When the elapsed time expires, the timer activates a small motor which opens a valve, exposing a hydraulic operating area to the tubing pressure below the tool. The pressure causes a tremendous upward force on the closing mandrel, which then moves up, also moving the closing sleeve up to shut in the well. This closing force makes EST very tolerant of sand or other debris that might enter the tool and make it hard to close. Added Accuracy and Reliability Since the electronics and motor are only used to port pressure to the hydraulic operating area of the tool and are not actually used to close in the well, the reliability of the tool is greatly increased. Combining the accuracy of an electronic timer with the pilot-operating hydraulic closing system has produced a highly versatile and accurate tool with excellent reliability. The EST may still be closed using slickline at any point during the test. Manual operation of the tool is independent of the automatic closure system. Features and Benefits Instantaneous closure, allowing for excellent early-time data quality Minimizes wellbore storage and/or phase redistribution effects by closing the well near the formation Provides quality reservoir data including early-time and build-up when coupled with memory gauges. Additional reservoir information available using fluid samplers Options to shut in at a pre-programmed time (electronic timer) or any time during the test using manual shut in (slickline) available with redundant actuation methods Can pump open tool to aid in equalization Excellent timing accuracy with electronics Temperature rating of 320F (160C) Three tool sizes: 2 3/8, 2 7/8, and 3 1/2-in. Rated for sour service to 320F per NACE MR-0175-98

Electronic Shut-In Tool (EST)Size in. 3 1/2* 2 7/8** 2 3/8*** OD ID in. (mm) in. (mm) 2.61 (66.29) 2.15 (54.61) 1.74 (44.19) 2.00 (50.8) 1.50 (38.10) 1.12 (28.45) Internal Flow Area in.2 (cm2) 3.15 (20.323) 1.76 (11.355) 0.99 (6.387) Flow Ports Flow Area in.2 (cm2) 2.37 (15.290) 3.14 (20.258) 1.35 (8.710) Make-Up Length in. (m) 90.71 (2.30) 91.42 (2.32) 91.42 (2.32) Total Length in. (m) 92.96 (2.36) 93.67 (2.38) 93.67 (2.38) Differential Rated Pressure (at closing sleeve) psi (kPa) 7,500 (51 711) 7,500 (51 711) 10,000 (68 900) Air Chamber Rating psi (kPa) 15,000 (103 422) 15,000 (103 422) 15,000 (103 422) Maximum Temperature F (C) 320 (160) 320 (160) 320 (160)

Electronic Shut-In Tool

*Used with Halliburton Otis 2.813-in. XN nipple with XO equalizing sub **Used with Halliburton Otis 2.313-in. XN nipple with XO equalizing sub ***Used with Halliburton Otis 1.875-in. XN nipple with XO equalizing sub The EST is designed to operate in H2S environments in temperatures up to 320F when used in accordance with 11.7 of NACE MR-0175-98. The lock mandrel/equalization sub used in conjunction with the EST may have a smaller flow area than the EST flow ports area and/or EST flow area.


HAL1086

3-17

SG-15 Gauge CarrierThe SG-15 gauge carrier is a 5.0-in. OD 2.25-in. ID external gauge carrier that has an offset OD and carries two Halliburton or third party gauges. The OD of this carrier is offset 0.4-in. from the ID. The ID of the tool is concentric with the tubing string so that the 2.25 ID is always maintained for wireline tool or drop bar passage. Depending on which of the various end adapters are run on the tool, the effective OD of the tool varies between 5.00-in. and 5.40-in. The tool features metal-to-metal seals backed up by electrometric seals. The tool is available in two versions. The standard gauge carrier carries standard length gauges. The long version carries Halliburton gauges which are equipped with one additional battery pack (stack pack). Both carriers are designed to carry 1.25-in. OD gauges. These tools are designed for the most severe well conditions including sour gas and very high temperature environments. Features and Benefits Permits unrestricted flow through the tools Allows wireline operations to be run Allows measurement in annulus Easy to install and retrieve gauges

SG-15 Gauge CarrierNominal Tool Size in. 3 3 7/8 5 5 Long Version OD in. (cm) 3.00 (7.62) 3.90 (9.91) 5.03 (12.78) 5.03 (12.78) ID in. (cm) 1.00 (2.54) 2.25 (5.72) 2.25 (5.72) 2.25 (5.72) Thread Connections 2 1/4 CAS 2 3/8 PH6 2 7/8 CAS 3 7/8 CAS 3 7/8 CAS Service Temperature* F (C) 450 (232) 450 (232) 450 (232) 450 (232) Length in. (cm) 98.00 (248.920) 201.97 (513.00) 202.00 (513.08) 224.5 (570.23) Tensile Rating** lb (kg) 156,000 (70 761) 140,000 (63 504) 285,000 (129 276) 285,000 (129 276) Working Pressure*** psi (bar) 15,000 (1034) 15,000 (1034) 15,000 (1034) 15,000 (1034) Number of Gauges 1 1 2 2 H2S Service F (C)

Documents

Hallibuton Well test manual