United States
Environmental Protection
Agency
Office of Research and
Development
Washington DC 20460
EPA/600/R-98/075
July 1998
Potential for Invasion of
Underground Sources of
Drinking Water through
Mud-Plugged Wei Is:
An Experimental Appraisal
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POTENTIAL FOR INVASION OF UNDERGROUND SOURCES OF DRINKING
WATER THROUGH MUD-PLUGGED WELLS: AN EXPERIMENTAL APPRAISAL
by
Marvin D. Smith
Gary F. Stewart
Randolf L. Perry
William A.Holloway
Jackie D. Holman, Jr.
Mike D. Smith
Charles D. Tautfest, Jr.
Gary Overton
Oklahoma State University
Stillwater, Oklahoma 74078
Cooperative Agreement CR-818319
Project Officer
Don C. Draper
Subsurface Protection and Remediation Division
National Risk Management Research Laboratory
Ada, Oklahoma 74820
NATIONAL RISK MANAGEMENT RESEARCH LABORATORY
OFFICE OF RESEARCH AND DEVELOPMENT
U. S. ENVIRONMENTAL PROTECTION AGENCY
CINCINNATI, OHIO 45268
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DISCLAIMER
The research reported upon in this document was funded wholly or in part by
the United States Environmental Protection Agency under cooperative agreement CR-
818319 to Oklahoma State University. The report has been subjected to the Agency's
peer and administrative review, and has been approved for publication as an EPA
document Mention of trade names or commercial products does not constitute
endorsement or recommendation for use.
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FOREWORD
The U.S. Environmental Protection Agency is charged by Congress with
protecting the Nation's land, air, and water resources. Under a mandate of national
environmental laws, the Agency strives to formulate and implement actions leading to
a compatible balance between human activities and the ability of natural systems to
support and nurture life. To meet these mandates, EPA's research program is
providing data and technical support for solving environmental problems today and
building a science knowledge base necessary to manage our ecological resources
wisely, understand how pollutants affect our health, and prevent or reduce
environmental risks in the future.
The National Risk Management Research Laboratory is the Agency's center for
investigation of technological and management approaches for reducing risks from
threats to human health and the environment. The focus of the laboratory's research
program is on methods for the prevention and control of pollution to air, land, water,
and subsurface resources protection of water quality in public water systems;
remediation of contaminated sites and ground water; and prevention and control of
indoor air pollution. The goal of this research effort is to catalyze development and
implementation of innovative, cost-effective environmental technologies; develop
scientific and engineering information needed by EPA to support regulatory and policy
decisions; and provide technical support and information transfer to ensure effective
implementation of environmental regulations and strategies.
This report contributes to that knowledge which is essential in order for EPA to
establish and enforce pollution-control standards which are reasonable, cost-effective
and which provide adequate environmental protection for the American public.
linton W. Hall
Subsurface Protection and Remediation Division
National Risk Management Research Laboratory
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ABSTRACT
The Hazardous and Solid Waste Amendment of 1984 requires the
Environmental Protection Agency to assess environmental suitability of liquid-waste
injection into subsurface rock. Accordingly, the reaction among injected wastes,
reservoirs, and original formation fluids is under evaluation.
The main objective of the feasibility study described here was to test the
hypothesis that properly plugged wells are effectively sealed by drilling mud. In the
process of testing the hypothesis, evidence about dynamics of building mud cake on
the wellbore-face was obtained, as well as comprehension of changes that occur in
drilling mud from the time it is placed in a well until it reaches equilibrium.
A system was developed to simulate (a) building mud cake in a borehole; (b)
plugging the well; and (c) injecting salt water in a nearby well, with concomitant
migration of salt water into the plugged well. The system "duplicated" reservoir
pressures, mud pressures, and reservoir-formation characteristics that develop while
mud cake is built, as in drilling a well. Salt-water injection was simulated, to monitor
any migration of fluid through a cylindrical synthetic-sandstone reservoir that was 3 ft.
in diameter and 2 ft. thick. Porosity and permeability of the sandstone were similar to
those of several natural reservoirs.
A 2100-ft. well and ancillary equipment permitted controlled variation of
simulated depth, porosity and permeability of reservoir rock, fluid composition, fluid
pressure, injection pressure, and mud properties. Data were recorded continuously
by computer.
Pressures commensurate with those in 5000-ft.-deep wells were to be
measured; associated differential pressures were required. A system developed to
measure differential mud pressures included undiminished pressure-transmittal by
diaphragm-interface.
Also, a high-pressure, low-flow-rate, high-accuracy flow meter system was
developed to monitor the slightest movement of fluid. Flow meters were developed to
measure (a) fluid from the reservoir, (b) mud-column flow from above the reservoir,
and (c) salt water under injection.
A second system was developed to simulate the building of mud cake on small
cores of sandstone, nine at a time. This is the multi-core Mud-cake and Permeability
IV
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(M&P) System, which is designed to provide real-time information about the second-
by-second characteristics of liquid flow through porous media; movement of clean
water was monitored, as were buildup of mud-cake and seepage of water through
mud cake.
Special tamping equipment was developed to make cores of artificial rock that
were 5 inches in diameter. A larger system was built to tamp the cores that were 3 ft.
in diameter. These artificial cores and cores of natural sandstone were used in the
Mud-cake and Permeability System; of course, only artificial sandstone was used in
the Simulated Injection System.
Two in-place systems provided potential for extensive testing of the many
variables that influence effective plugging of boreholes. Several variables were
studied to a limited extent. Basic tests of the Simulated Injection System were
incomplete, because of failure of some down-hole devices.
Properties of core-plugs of natural sandstone were more varied than properties
of core-plugs of artificial sandstone. Mud-plugging tests of natural sandstone indicate
interstitial materials swell or migrate, and plug pore-throats.
When core-plugs were tested for permeability to water, large differences were
observed among plugs that varied 4% or less in nitrogen-permeability. In core-plugs
with less than 500 md of nitrogen-permeability, permeability to water generally was
only 25% to 50% of nitrogen-permeability. In core-plugs of 1000 md or more of
nitrogen-permeability, permeability to water generally was 25% to 100% of nitrogen-
permeability.
Consider two processes: (1) mud-cake buildup, during which mud was
circulated through the system, and (2) mud-shut-in pressure buildup, during which
mud was under pressure and mud filtrate migrated through mud cake. Under both
conditions, as pressure increased permeability generally decreased, until break-
through occurred. This basically means that flow rates are proportionally higher at the
lower pressures, and the absolute flow rates are higher at lower pressures — except
when break-through occurs.
Mud-cake buildup liquid permeability increases linearly, on a common-
logarithmic scale, in positive correlation with water permeability on a linear scale.
This trend holds for artificial sandstone and for natural sandstone tested during the
course of this project.
Inferences drawn from settling-tube experiments are as follows: In a plugged
and abandoned well, the particulate fraction of drilling mud settles; above the column
of particulate material, mud cake would separate water in a borehole from reservoir-
rock. This circumstance would be analogous to the in-situ condition of this project, in
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which pressure-driven water migrated (slowly) through mud cake. Experiments in this
project showed that the ratio of in-situ permeability to water-permeability decreases
exponentially on a common-logarithmic scale, relative to linear increase in water-
permeability.
VI
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CONTENTS
Disclaimer ii
Foreword iii
Abstract iv
Figures xi
Tables xiv
Section 1: Introduction 1.1
Section 2: Conclusions 2.1
Section 3: Recommendations 3.1
Section 4: Test-facility Design, Development and Function 4.1
General Description of Facility 4.1
Introduction 4.1
Total-facility Schematic Diagram 4.3
Components Simulating Wellbore Above Zone of Fresh Water.... 4.12
Simulated Wellbore-and-mud Column Below'Zone of Fresh
Water 4.12
Mud-column Flow Meter 4.13
Simulated Water-Reservoir Zone 4.14
Introduction 4.14
Artificial Reservoir: Function and Construction 4.14
Artificial-reservoir Housing 4.17
Simulated Reservoir Rock 4.19
Rock Porosity and Permeability Measurements 4.20
Simulation of Drilling Process to Build Mud Cake 4.25
Simulated Wellbore and Injection Zone Below Reservoir 4.26
Introduction 4.26
Well Configuration 4.26
Measurement and Control 4.27
Core Plug Development and Testing 4.27
Mud-cake and Permeameter System 4.31
Monitoring of Drilling Mud 4.39
Section 5: Instrumentation: Design and Application 5.1
Introduction 5.1
Instrumentation Design Features 5.1
Multiplexer System for Down-hole Sensors 5.1
Temperature Sensors 5.1
Diaphragm Housing 5.1
Pressure Transducers 5.2
Differential-pressure Transducers 5.3
vii
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Piston Flow Meters 5.4
Float Flow Meter 5.4
Measurements of Permeability and Porosity 5.5
Applications of Instruments 5.5
Section 6: Data-acquisition System 6.1
Introduction 6.1
Down-hole Data-acquisition System 6.2
Computer 6.2
Flow-meter Controller 6.2
Data-acquisition Process 6.2
Mud-cake and Permeability Data-acquisition System 6.3
Mud-cake and Permeability Software 6.4
Section 7: Results of tests 7.1
Simulated Injection System Tests 7.1
Summary, Test-table Variables, Simulated Injection System
Tests 7.1
Porosity of Artificial Reservoir 7.1
Permeability of Artificial Reservoir 7.2
Mud-cake and Permeability Tests 7.5
Summary, Test-table Variables; Mud-cake and Permeability
Tests 7.5
Properties of Drilling Mud 7.7
Liquid-permeability and Gas-permeability 7.7
Comparisons of Permeability 7.7
Relationship of Nitrogen-permeability and Water-
permeability 7.13
Effects of Pressure on Permeability 7.17
Trends Among Permeabilities Under Different
Environments 7.23
Settling-column Characteristics of Mud 7.27
Appendix A: Drawings and Development Associated with the Artificial
Reservoir A1
Rock Development, Testing and Pouring Procedure A1
Development of the Artificial Reservoir A1
General Procedures in Development A1
Procedure for Constructing Artificial Reservoir A5
Core-plugs for Mud-cake and Permeability Tests A8
Outermost Part, Artificial Reservoir A10
Sealing of Reservoir at Contacts with Blind Flanges A16
Artificial-reservoir System A16
Attachment 1 A22
Attachment 2 A24
Appendix B: Drawings and Development of Instrumentation B1
Diaphragm Housing B1
Pressure and Differential-pressure Transducers B3
viii
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Design of Piston-type Flow Meter B3
Appendix C: Instrument Calibration C1
Pressure Transducers and Differential-pressure Transducers C1
Flow-meter Calibration C6
Calibration Procedure for Simultaneous Flow-meter Operation C11
Appendix D: Quality Assurance Plan D1
Project Objectives, Data Use, and Acceptance Criteria D1
Project Objectives D1
Data Use D1
Acceptance Criteria D2
Data-quality Objectives D2
Selection of Sampling Locations and Collection of
Samples D3
Handling, Identification and Storage of
Samples D5
Methods of Measurement and Performance
Characteristics D5
Injection Depth D6
Depth of Artificial Reservoir (Invaded Formation) D6
Artificial-reservoir Pressure (Invaded Zone) D6
Injection Pressure D8
Reservoir Properties D8
Fluid Properties D8
Test Sequence D9
Standards for Measuring Mud-properties and Reservoir-
properties D11
Quality Control and Quality Assurance D11
Data Reduction and Reporting D11
Characteristics of Computer Data System D12
Uncertainties in Measured Values D14
Appendix D-1: Quality Assurance Plan D15
Structure of the General Experiment: Steps within One Cycle D15
Structure of Simulated Injection System (SIS) Tests D15
Structure of Mud-column Settling (CS) Tests D19
Structure of Mud-cake and Permeability (M&P) System Tests D19
Appendix E: Numbers and Names of Valves, Mud-cake and Permeability
System \ E1
Valves Located Outside EPA Outdoor Laboratory Building E1
Valves Located Inside EPA Outdoor Laboratory Building E2
Appendix F: Operating Procedures: Summary Listing F1
Operating Procedure 1.1: Preparation of Artificial-reservoir housing
to Receive Sand Mixture F6
Operating Procedure 1.2: Preparation of Cores, 5 Inches in Diameter F7
Operating Procedure 1.3: Electrohydraulic Control of Core-tamping
IX
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Device F10
Operating Procedure 1.4: Preparation of Sand Mixture F11
Operating Procedure 1.5: Filling of Housing with Sand Mixture F12
Operating Procedure 1.6: Emplacement of Top Flange, Artificial-
reservoir Housing F12
Operating Procedure 2.1: Calibration of Pressure Gauges F13
Operating Procedure 2.2: Calibration of Pressure and Differential-
pressure Transducers F14
Operating procedure 2.3: Calibration of Temperature Sensors F14
Operating Procedure 2.4: Calibration of Flow Meters F15
Operating procedure 2.5: calibration of Mud-flow-rate System F17
Operating Procedure 2.6: Calibration of Salt-water Turbine Meter F18
Operating Procedure 3.0: Mounting Diaphragm-seal Housings F19
Operating Procedure 3.1: Mounting of Differential-pressure
Transducers F21
Operating Procedure 3.2: Mounting of Pressure Transducers F21
Operating Procedure 3.3: Mounting of Temperature Transducers F22
Operating Procedure 3.4: Mounting of Multiplexers F22
Operating Procedure 3.5: Placing of Flow Meters F23
Operating Procedure 3.6: Mounting of Pressure Gauges F23
Operating Procedure 4.0: Pipe Selection F24
Operating Procedure 4.1: Positioning Casing Joint F24
Operating Procedure 4.2: Connecting instrumentation Lead-lines F25
Operating Procedure 4.3: Mechanical Installation of First Joint F25
Operating Procedure 4.4: Mechanical Installation of Second and All
Other Joints F29
Operating Procedure 4.5: Recording Instrumentation Position and
Location on Casing String F30
Operating Procedure 4.6: Securing Top Joint and Lead-lines in
Wellhead F30
Operating Procedure 5.1: Emplacement of Water in Casing String for
Calibration Check of Down-hole Sensors F30
Operating Procedure 5.2: Activation and Check-out of Computerized
Data-acquisition System F31
Operating Procedure 5.3: Initial Calibration-check of Sensors F31
Operating Procedure 6.1: Measuring Porosity of Artificial Reservoir
within Housing F32
Operating Procedure 6.2: Measuring Permeability of Artificial
Reservoir within Housing F33
Operating Procedure 7.1: Containment of Fluid within Artificial
Reservoir During Removal of Instruments F33
Operating Procedure 7.2: Installation of Reservoir Pick-up Assembly. F34
Operating Procedure 8.1: Mixing of Mud According to Oklahoma
Corporation Commission's Standards for Well-plugging F34
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Operating Procedure 8.2: Homogenization of Drilling Mud F35
Operating Procedure 8.3: Sampling and Testing of Drilling Mud F35
Operating Procedure 8.4: Emplacement of Drilling Mud in Casing
String F35
Operating Procedure 8.5: Removal of Drilling Mud from Casing
String F35
Operating Procedure 9.1. Placement of Reservoir Stand F36
Operating Procedure 9.3: Placement of Artificial Reservoir on
Reservoir Stand F36
Operating Procedure 10.1: Homogenization of Drilling Mud F37
Operating Procedure 10.2: Displacement of Packer F37
Operating Procedure 10.3: Adjustment of Flow Rate and Back-
pressure F38
Operating Procedure 10.4: Monitoring of Mud-filtrate Flow Rate F38
Operating Procedure 10.5: Sampling and Testing of Drilling Mud F38
Operating Procedure 10.6: Shut-down Procedure and Line Removal. F38
Operating Procedure 10.7: Refined Adjustment of Pressure to
Prescribed Magnitude: F38
Operating Procedure 11.1: Monitoring of Mud Column for Differential
Pressure, Pressure and Temperature F39
Operating Procedure 11.2: Monitoring of Mud Column at Simulated-
depth Conditions, for Differential Pressure, Pressure, and
Temperature F39
Operating Procedure 12.1: Activation of Salt-water Injection System.. F39
Operating Procedure 12.2: Monitoring and Recording
Comprehensive Pressure Differentials, Pressures and Flow Rates F39
Operating Procedure 12.3: Increasing Injection Pressure in
Response to Undetectable Flowfrom Reservoir F40
Operating Procedure 12.4: Increasing Injection Pressure in
Response to Low Rates of Flowfrom Reservoir F40
Operating Procedure 12.5: Termination of Injection in Response to
Maximized Flow or Pressure F40
Operating Procedure 12.6: Removal of Instrumentation from
Artificial-reservoir Housing F40
Operating Procedure 13.2: Disconnecting Reservoir Housing from
Casing String F41
Operating Procedure 13.3: Installation of Reservoir Pick-up
Assembly and Movement of Reservoir Housing F41
Operating Procedure 14.1: Removal of Artificial Reservoir from
Housing F41
Operating Procedure 14.2: Mapping and Labeling of Reservoir
Surface for Random Sampling F42
Operating Procedure 14.3: Collection of Random Samples F42
Operating Procedure 14.4: Labeling and Storage of Samples F42
XI
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Operating Procedure 15.1: Displacing Drilling Mud with Water F43
Operating Procedure 15.2: Calibration Check of Sensors F43
Operating Procedure 15.3: Displacing Water with Air F43
Operating Procedure 15.4: Shut-down of Computerized Data-
acquisition System F43
Operating Procedure: 16.1 Documentation of Software for Reduction
of Data F44
Operating Procedure 16.2: Documentation of Software for Analysis
of Data F44
Operating Procedure 16.3: Methods for Recording of Data F44
Operating Procedure 16.4: Methods for Secure Storage of Data F44
Operating Procedure 16.5: Methods of Reducing Data F44
Operating Procedure 16.6: Methods for Validating Data F45
Operating Procedure 16.7: Definition of Data-quality Indicators F45
Operating Procedure 16.8: Methods for Evaluating Quality of Data.... F46
Operating Procedure 16.9: Methods for Presenting Data F46
Operating Procedure 16.10: Reporting of Conclusions F46
Operating Procedure 17.1: Multiple-core Mud-cake and Permeability
Test Procedure F47
Operating Procedure 17.2: Preparation for Mud-cake and
Permeability Test F54
Operating Procedure 17.3: Recording Numbers of Cores F54
Operating Procedure 17.4: Measuring Dry-weights of Beakers F55
Operating Procedure 17.5: Placement of Cores into Rubber Core-
holder sleeves F56
Operating Procedure 17.6: Placement of Core and Core-holder Cap
onto M&P Subassembly F56
Operating Procedure 17.7: Placement of Beakers under Discharge-
tubes on M&P Subassemblies F56
Operating Procedure 17.8: Setting Valve-positions on M&P
Subassemblies ' F57
Operating Procedure 17.9: Filling M&P Subassembly Chamber with
Water F58
Operating Procedure 17.10: Activate Computer: M&P Software
Operation F60
Operating Procedure 17.11: Passage of Water Through Test
Core F62
Operating Procedure 17.12: Shut-down Procedure for Software F62
Operating Procedure 17.13: Recording Wet-weight of 100-ML
Beakers P63
Operating Procedure 17.14: Shut-down Procedure, M&P
Subassemblies F63
Operating Procedure 17.15: Shutting Down Computer F66
Appendix G: Simulated Lower Wellbore Drawings G1
XII
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Appendix H: Multicore-permeameter Tests H1
Appendix I: Porosity and Permeability: Core Plugs 11
Introduction 11
Estimates of Porosity 14
The Set of 32 Core Plugs 14
The Set of 99 Core Plugs 15
Estimates of Porosity, M & P Tests 17
Estimates of Porosity, M & P Tests, Wet Core Plugs 19
Estimates of Permeability 110
Permeability to Nitrogen 110
Selected References 112
Appendix J: Simulated Injection System, Mud-settling Permeabilities J1
Appendix K: Mud-settling Tests: Data Recorded from Mud-settling
Tubes K1
Appendix L: Mud Properties: M & P and SIS Tests L1
Appendix M: Artificial Reservoir 2: Porosities and Permeabilities of Core
Plugs M1
Appendix N: Computer Software N1
Software Highlights N1
Down-hole and Top-side Data Acquisition N1
M&P Data Acquisition N2
Appendix N, Attachment 1, Program: FINALDH1.BAS N4
Appendix N, Attachment 2, Program: FLMTRCALBAS N8
Appendix N, Attachment 3, Program: PERMTST1.DOC N11
Appendix N, Attachment 4, Program: MUDTEST.BAS N14
Appendix N, Attachment 5, Program: DELTA3T.BAS N17
Appendix N, Attachment 6, Program: AVG1.BAS N24
Appendix N, Attachment 7, Program: AVG1-H.BAS N26
Appendix N, Attachment 8, Program: V-AVG1.DOC N28
XIII
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FIGURES
Figure Page
4.1 Representative injection well and abandoned well 4.2
4.2 Plan-view schematic drawing of test facility 4.4
4.3 View of salt-water tank and effluent tank 4.5
4.4 Mud pump, mud mixers, and mud tank. 4.6
4.5 Mud-pipe network with casing and tubing 4.7
4.6 Schematic drawing, system for mud-cake buildup and for injection.. 4.8
4.7 Simulated Injection System, instrument console 4.9
4.8 Artificial reservoir connected to 2100-ft. well 4.10
4.9 Data-acquisition system for simulated-injection-system test 4.11
4.10 Large tamper in position to tamp artificial reservoir 4.15
4.11 Hydraulic pump and controls for large tamper 4.16
4.12 Large core-boring machine on top of artificial reservoir 4.21
4.13 Close-up photograph, large core-boring machine 4.22
4.14 Small core-boring machine coring artificial reservoir 4.23
4.15 Small core-boring machine with vacuum system 4.24
4.16 Small tamper with 5-in. core mold 4.28
4.17 Small tamper with hydraulic system and controller '4.29
4.18 Small core-boring machine 4.30
4.19 Ruska nitrogen-permeameter and Ruska water-permeameter 4.32
4.20 Schematic drawing, M & P system 4.33
4.21 Data-acquisition system, M&P tests _ 4.34
4.22 Mud-cake and Permeability test system 4.35
4.23 Instruments of M & P system, and "OHAUS" scale 4.36
4.24 Mud-properties test station 4.37
4.25 Dimensions of mud-settling columns 4.40
7.0 Pressure and permeability history, SIS reservoir, 12 Dec. 1994 7.4
7.1 Water-permeability as a function of nitrogen-permeability, core-
group 5/24/94 7.8
7.2 Mud-cake buildup and in-situ permeability as a function of water-
permeability, core group 5/24/94 7.10
7.3 Duration and frequency, time between flow, sensor M&P 2.2, test
of 5/24/94 7.11
7.4 Duration and frequency, effluent flow, sensor M&P 2.2, test of
5/24/94 7.12
7.5 Duration and frequency, time between flow, sensor 1.1, test of
6/7/94 7.14
7.6 Duration and frequency, time between flow, sensors M & P 1.2 and
3.2, test of 6/7/94 7.15
7.7 Comparison, water-permeability versus nitrogen-permeability, all
XIV
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tests 7.16
7.8 Effects, pressure on permeability, mud-cake buildup and shut-in
conditions, core group 4/27/94 7.18
7.9 Effects, pressure on permeability, mud-cake buildup and shut-in
conditions, core group 12/7/93 7.19
7.10 Effects, pressure on permeability, in-situ conditions, core group
12/7/93 7.21
7.11 Effects, pressure on mud-cake buildup and mud-shut-in effluent
flow rates, core group 12/7/93 7.22
7.12 Average mud-cake buildup permeability versus pressure, all tests
shown in Tables H1-H10 .' 7.24
7.13 Relationship, test cores, average mud-cake buildup permeability
versus average water-permeability, all tests shown in Tables H1-
H10 7.25
7.14 Ratio, in-situ permeability to water-permeability versus water-
permeability, 50-psi tests 7.26
7.15 Rate, settlement of mud, Columns 2 and 3. Mud-cake buildup test
8/20/92 7.28
7.16 Settlement of mud in tubes filled from top compared to mud in tubes
filled from bottom 7.28
A1 Vials of Oklahoma No. 1 quartz sand and "12/20 frac sand"............. A2
A2 Disc of hardened resin, cementing agent in artificial sandstone A3
A3 Standard Proctor mold, hammer and sample-remover A4
A4 Molds 4 in. and 1 in. in diameter and bench-test samples, artificial
reservoir A6
A5 Interior, artificial-reservoir housing during emplacement, central
part of reservoir A7
A6 Model, artificial reservoir, sand with resin binder A11
A7 Plot, porosity compared to permeability, artificial reservoir A12
A8 Artificial reservoir housing, view into central chamber A13
A9 Interior, artificial reservoir housing, during emplacement of
reservoir A14
A10 Completed reservoir, cured and cored A15
A11 Lower side, blind flange of artificial reservoir housing A17
A12 Tabs of polycarbonate gasket material and sample of artificial
reservoir A18
A13 Knife-edge compression test, sample of artificial reservoir A19
A14 Specimens artificial reservoir, bonded to devices used in testing for
tensile strength A20
A15 Diagram, placement of artificial reservoir rock. A21
B1 Detail, diaphragm housing, interface between mud and water B2
B2 Configuration, above-ground pressure transducers B4
B3 Configuration, down-hole pressure transducers mounted on 51/2-
in. casing B5
xv
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TABLES
Table Page
A1 Mixture for outer shell, artificial reservoir A9
A2 Mixture for simulated-injection-system reservoir A9
B1 Pressure transducer ratings B7
D1 Testing sequence for mud-plugging evaluation D10
D2 Variables, maximal readings, expected errors, CS, SIS and M & P
tests D14
H0.1 Code to identification of cores (through Table H0.5, p. H6) H2
H1.1 M & P test data, sandstone, Bamsdall Formation, 500 md
permeability (through Table H1.15, p. H21) H7
H2.1 M & P test data, sandstone, Wellington Formation, 350 md
permeability (through Table H2.6, p. H27) H22
H3.1 M & P test data, artificial sandstone, 2000 md permeability
(through Table 3.9, p. H36) H28
H4.1 M & P test data, artificial sandstone, 2000 md permeability
(through Table H4.6, p. H42) H37
H5.1 M & P test data, artificial sandstone, 1500 md permeability
(through Table H5.6, p. H48) H43
H6.1 M & P test data, artificial sandstone, 1000 md permeability
(through Table H6.6, p H54) H49
H7.1 M & P test data, artificial sandstone, 1250 md permeability
(through Table H7.6, p. H60) H55
H8.1 M & P test data, artificial sandstone, 500 md permeability (through
Table H8.6, p. H66) H61
H9.1 M & P test data, natural sandstone, Pony Creek Shale, 1250 md
permeability (through Table H9.6, p. H72) H67
H10.1 M & P test data, natural sandstone, Hughes Creek Shale, 200 md
permeability (through Table H10.12, p. H84) H73
H11.1 M & P test data, artificial sandstone, 0.9-2.7 md permeability
(through Table 11.6, p. H90) H85
M Core-plug analyses, K & A Laboratories 13
J1 Artificial-reservoir permeability during settling conditions 12/10/94
-12/17/94 J2
K1 Mud-settling test 82092, settling tube 2 K2
K2 Mud-settling test 82092, settling tube 3 K2
K3 Mud-settling test 3894, settling tube 1 K3
XVI
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K4 Mud-settling test 3894, settling tube 2 K3
K5 Mud-settling test 42894, settling tube 1 K4
KB Mud-settling test 42894, settling tube 2 K4
K7 Mud-settling test 5394, settling tube 1 K5
KB Mud-settling test 5394, settling tube 2 K5
K9 Mud-settling test 51294, settling tube filled from top K5
K10 Mud-settling test 51294, settling tube filled from bottom K6
K11 Mud-settling test 51894, settling tube filled from top K6
K12 Mud-settling test 51894, settling tube filled from bottom K6
K13 Mud-settling test 52594, settling tube filled from top K7
K14 Mud-settling test 52594, settling tube filled from bottom K7
K15 Mud-settling test 6194, settling tube filled from top K7
K16 Mud-settling test 6194, settling tube filled from bottom K8
K17 Mud-settling test 62294, settling tube filled from top K8
K18 Mud-settling test 62294, settling tube filled from bottom K8
K19 Mud-settling test 71894, settling tube filled from top K8
K20 Mud-settling test 71894, settling tube filled from bottom K9
K21 Mud-settling test 111794, settling tube filled from bottom K9
K22 Mud-settling test 111894, settling tube 1 K9
K23 Mud-settling test 12294, settling tube filled from bottom K9
L1 Properties of mud used in M & P and SIS tests L2
M1.1 Estimates, porosity, cores used in M & P tests (through Table
M1.6, p. M7) M2
M2 Porosities and permeabilities, core plugs, artificial reservoir 2 M8
XVII
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SECTION 1
INTRODUCTION
The Environmental Protection Agency is required by the Hazardous and Solid
Waste Amendment of 1984 to assess the environmental suitability of injection of liquid
wastes into subsurface formations. The Agency's approach to this matter is
composed of three general activities: (1) to evaluate the construction of injection wells
and the capability for monitoring them, in order to detect failures; (2) to assess the
relationship among the rock-stratigraphic units, the fluids injected, and the integrity of
the bounding confining beds; and (3) to evaluate the reaction among the injected
waste, the formation, and the formation fluids.
The primary objective of the research described here is to test this hypothesis:
Drilling mud in abandoned, properly plugged wells effectively seals the borehole.
Therefore, if fluids injected into reservoirs at depth were to migrate up the boreholes
of properly plugged wells, filter cake nevertheless would prevent passage of these
fluids into other reservoirs. The alternate hypothesis needs no elaboration. The
principal object of inquiry can be expressed as a question: "Does a predictable
relationship exist among the standard measured properties of drilling mud, the in-situ
well-plugging fluid, the permeability of the adjacent reservoir, and the differential-
pressure regime?"
Research described herein was conducted in two general stages, the first
under EPA CR 814239, the latter under EPA 818319. Because the endeavors cannot
be separated by purpose, procedure or physical facilities, the results described herein
have to do with both projects. Otherwise, the reader would be subject to the labor and
confusion of integrating descriptions of the former work and the present work.
A system was developed to determine permeabilities of cores in the presence
of drilling mud. Mud cake was built on small cores of artificial sandstone and of
natural sandstone. Porosity and permeability of the cores were designed to vary in
manners that are similar to variation in actual sandstone reservoirs. Amounts of mud
filtrate that passed through the cores were measured drop-by-drop. Rates of
movement of filtrate were measured as well. Drilling mud was replaced by fresh water
in order to estimate the effects of water opposite mud cake, under differential
pressure.
1.1
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Settling and differentiation rates of drilling muds were simulated by construction
and monitoring of mud-filled transparent cylinders.
A 2100-ft. well and ancillary facilities compose a system that permits controlled
variation of simulated down-hole conditions, including depth, porosity and
permeability of reservoirs, compositions of fluids, pressures of fluids, injection
pressures, and properties of plugging agents. Instrumentation was designed and
assembled, or manufactured, in order to test the feasibility of monitoring variation in
pressures and rates of flow of fluids, under several regimes of injection. Computer
software was written for continuous reception and recording of data. Methods were
developed for construction of an artificial sandstone reservoir; porosity and
permeability of this reservoir and some actual reservoirs are similar.
Testing of cores by injection of drilling mud under pressure shows evidence of
a trend: Effective permeability is reduced as differential pressure is increased - up to
the point of breakthrough; thereafter effective permeability increases.
1.2
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SECTION 2
CONCLUSIONS
1. For the cores and types of mud tested in this project, mud-cake buildup
permeability increases linearly on a common-logarithmic scale, with respect to linear
increase in permeability to water. The ratio of in-situ-fluid permeability to water-
permeability decreases exponentially on a logarithmic scale, with respect to linear
increase in water-permeability.
2. Permeability using nitrogen as the fluid is higher than permeability of the
same core plug using water. Depending upon the conditions of the rock and
contaminants, the ratio of the two permeabilities ranges from about 0.25 to 1. Even
with these variations in the two permeabilities, there is a trend in the mud-cake buildup
permeability with respect to water permeability and also in-situ-fluid permeability with
respect to water permeability. Therefore defining the trending of permeability
relationships is feasible for relating water permeability to the potential mud or in-situ
permeabilites for given mud characteristics and differential pressures.
3. With cores tested in this project, a trend exists which shows that an increase
in differential pressure — in a mud environment — reduces the effective permeability up
to a critical pressure; then break-through seems to occur, accompanied by an effective
increase of permeability. Among a set of cores with similar permeability to nitrogen, all
exposed to the same mud-pressure differential, the critical differential pressure is not
consistent.
4. In none of the tests run during this project was the flow through the core
stopped; but the flow rate was extremely slow. In some instances, drips occurred at
intervals of as long as 400 seconds.
5. The multi-core mud-cake-and-permeability (M&P) system has been
demonstrated to provide real-time information about the second-by-second flow of
water through mud cake, and characteristics of liquid flow through porous media under
three sets of conditions: (a) clean water only, (b) during mud-cake build up, and (c)
when water seeps through mud cake.
6. Drilling mud in glass tubes settled, so as to separate into two fractions:
drilling mud denser than 9 Ib. per gallon, overlain by water that contains very small
amounts of clay. Separation of drilling mud into two fractions continued throughout the
longest test - 850 days. Mud tended to settle faster in tubes filled from the top. The
implication regarding mud-plugged wells is that the paniculate fraction of drilling mud
would settle and that water in the borehole would be separated from reservoir-rock by
mud cake deposited during stratification of the mud column. If fluid-pressure in the
2.1
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borehole were greater than formation-pressure but less than break-through pressure of
mud cake, then invasion of reservoir rock and mixing of fluids should be greater than
zero but less than volume sufficient to damage the reservoir within the consequential
future.
2.2
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SECTION 3
RECOMMENDATIONS
Major additions to a unique facility have been made during this contract period.
These improvements provide the capability of evaluating a large array of well-plugging
designs by use of the Mud-cake and Permeability System. Variables in this array
include flow rates, pressures, core types, mud and in-situ fluid in the simulated well
bores. To utilize this facility for tests to include, but not limited to the following topics is
recommended.
1. Obtain samples of natural rock from fresh-water aquifers and measure the
characteristics of them under simulated conditions of mud-plugged wells.
2. Complete a series of tests to determine the performance-envelope of
variables that could affect the plugging and protection of a reservoir. This set
of variables would include mud properties, well-to-reservoir differential
pressures, various rock properties, various injection-fluid properties and a
range of flow rates.
3. Investigate types of fluids and additives that would enhance the plugging
characteristics of drilling mud. These would be compared to standard fluids
and practices.
The Simulated Injection System designed to evaluate a large artificial reservoir
was not tested successfully, because of failure in some down-hole instruments and
because of down-hole leaks. Casing and all attachments should be withdrawn from the
hole and checked for leaks. Redesign of the mud-sensor interface is recommended,
with repair or replacement of damaged instruments, and repair of leaks. If this is done,
then evaluation of the system, and valid test results should be achievable.
3.1
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SECTION 4
TEST-FACILITY DESIGN, DEVELOPMENT AND FUNCTION
GENERAL DESCRIPTION OF FACILITY
INTRODUCTION
The facility is designed for testing under conditions that simulate a well
plugged with mud, for abandonment. A zone in the upper region of the hypothetical
well is an underground source of drinking water (protected zone, Figure 4.1), and the
intention is to not contaminate it. Below the fresh-water-bearing formation is a
formation used for injection (Figure 4.1), pressurized by disposal of salt water into a
nearby well. Pressure is translated through the injection zone to the abandoned well.
Therefore, potential exists for salt water to migrate up the wellbore and invade the
underground source of drinking water. The purpose of the testing design is to
estimate the array of conditions that could allow invasion of the zone of drinking
water.
The testing facility is divided into four basic areas, which are associated with
zones in a plugged and abandoned well, shown diagrammatically in Figure 4.1.
These areas are dedicated to study of the wellbore above the reservoir being
protected (region 1), the protected reservoir and wellbore (region 2), the wellbore
below the protected reservoir, and the salt-water disposal reservoir (region 3), and the
overall part of the facility that simulates drilling the well and building mud cake on the
wall of the wellbore. Regions 1 and 2 shown in Figure 4.1 are simulated by facilities
located above ground level, whereas region 3 is an actual well, 2100 ft. deep.
Building of mud cake is modeled in a pan: of the facility that is also above ground.
In the following sections of this report, the various components or assemblies
that combine to form the facility are discussed. Included is a brief description of each
component, a statement of its purpose, description of salient design features, and
description of its interaction or connection with other components or assemblies, of
controlling features, of associated instrumentation and of the type of data produced.
4.1
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•Salt Water Injection
Cased Salt
Water Disposal Well
Ground Level
Cement Plug
Region #1
Region #2
Region #3
Figure 4.1 Representative injection well and abandoned well.
4.2
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TOTAL-FACILITY SCHEMATIC DIAGRAM
Figure 4.2 is a general plan view of the facility. Individual systems are required
to obtain quantitative data about results of injecting salt water into a reservoir and
about the effects of invasion on a shallow, fresh-water-bearing formation in an
abandoned well nearby. The Assembly Stand (Location A, Figure 4.2) is the
mounting stand for the reservoir housing, used when the artificial-reservoir mix of
sand and resin is poured, and during the process of measuring porosity and
permeability of the reservoir. The salt-water tank, lines and pump, effluent tank and
connecting lines (Figure 4.3), mud tank, mud mixer, mud pump (Figure 4.4), controls
and pipe network (Figure 4.5) are clustered in the northeastern part of the facility
(Figure 4.2). Casing and tubing are stored on the pipe rack, and are moved to
Location B through the v-door on the northern part of the pipe rack.
In Figure 4.2, Location B is the operational position of the Simulated Injection
System (SIS) tests (Figure 4.6). A movable building houses the functional equipment
at this site and it is insulated and temperature-controlled. Figure 4.7 shows the SIS
instrumentation-and-control console, which provides pressure control for the
reservoir, for the wellbore and for water injection, as well as for measuring pressures,
temperatures and flow rates. In the right-hand side of Figure 4.7 is the artificial-
reservoir housing, which is shown in full view in Figure 4.8. On it are pressure
transducers, differential-pressure transducers, pressure gauges, temperature
sensors, lines connecting to the mud column above and to the wellbore below, and
effluent lines from the periphery of the reservoir housing. Pressure and temperature
sensors are on the casing down-hole to measure conditions that change during a test.
All data are obtained using a computer data-acquisition system (Figure 4.9), located
in the building described below.
About 30 ft. north of the test well (Location B, Figure 4.2) is a 40-ft.-long, 24-ft.-
wide steel building that houses the Mud-cake and Permeameter System, work tables,
venting hood, small tamping-machine, equipment for coring rock, gas and water
permeameters, computers and other equipment. Temperature is controlled by a
ground-source heat pump.
4.3
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PpeRack
for5-1/r
Casing
andTubtng
Figure 4.2 Plan-view schematic drawing of test facility.
4.4
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Figure 4.3 View of salt-water tank (foreground) and effluent tank (behind).
4.5
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Figure 4.4 Mud pump in foreground, small-volume mud mixer directly
behind, and mud tank with large-volume mud mixer above.
4.6
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Figure 4.5 Mud-pipe network (center) with casing and tubing on pipe rack behind.
4.7
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BlMdl
Vertical Flow
Meter
o
High Point
Air Bleed
Mud Mixer
Salt Water Injection Circuit
3/8- Tubing -^
Figure 4.6 Functional schematic drawing, basic structure of system for (1) mud-cake buildup in artificial
reservoir and (2) for injection.
-------
Figure 4.7 Simulated Injection System, instrument console.
4.9
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Figure 4.8 Artificial reservoir placed over and connected to the 2000-ft. well.
4.10
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Figure 4.9 Data-acquisition system for simulated-injection-system test.
4.11
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Figure 4.6 is a functional schematic drawing of the system for the SIS phase of
the testing project. It shows the general configuration of the components, their
interconnections, controls and instrumentation. Groupings of these components are
described below.
COMPONENTS SIMULATING WELLBORE ABOVE ZONE OF FRESH WATER
In actual wells, the wellbore above the protected zone (Figure 4.1) is to be
filled with drilling mud and capped with a cement plug. The specific requirements are
in regulations set out by the States. The simulation described herein is designed
according to the well-plugging requirements of the Oklahoma Corporation
Commission. Pressure on the wellbore would be dependent upon mud weight and
depth in the well. Therefore, to simulate the depth of a formation it is sufficient to
impose a pressure commensurate to the value determined by mud weight and depth.
Because the cement plug is stationary, but because the mud below it can move down
the wellbore and into formations under less pressure, it is necessary to provide fluid
sufficient to simulate this condition. Also, pressure must be maintained during
movement of fluid down the wellbore. As pressure increases in the wellbore due to
injection, the mud would move against the cement plug, and pressure in the entire
wellbore would increase. This condition also must be simulated.
Simulated Wellbore-and-Mud Column Below Zone of Fresh Water
A section of 7-in. casing was sized to hold enough mud to sweep about one-
half the pore volume of the most porous medium that we expected to test (container at
"High Point Air Bleed," Figure 4.6). This amount of mud is expected to place a final
seal on the mud cake (if indeed the extra mud is required) after circulation of mud
through the wellbore. If one container-full is insufficient, then the valve arrangement
is designed so that the container can be refilled during the test, with minimal
disturbance of test results. When the mud column is filled with mud and air is bled
from the system, then the nitrogen pressure is adjusted to make pressure in casing
above the artificial reservoir be commensurate to pressure in an abandoned well, at
the given depth. This nitrogen pressure is impressed upon water in the mud-column
flow meter and transmitted through the line between the flow meter and the simulated
wellbore-mud column. If the fluid level moves, fluid either has gone out the effluent
line or out a leak in the system. The system is designed so that data from the three
flow meters will determine whether a leak exists or fluid is being discharged to the
effluent tank.
Some of the design features associated with the simulated wellbore-and-mud-
column are a fill tee and bleed valve at the top of the column, a flow tee and three
valves at the bottom of the column, and a line connecting the column to the flow
4.12
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meter and to a check valve and a shut-off valve on the flow meter end (See diagram
near "High Point Air Bleed" container, Figure 4.6.).
During filling of the mud column, the valve between the high-point air bleed and
below the vertical flow meter (top-center, Figure 4.6) is closed, so that mud will not
enter the check valve. Before mud is placed in the column, the line from the flow
meter is filled with water. The high-point air-bleed valve on top of the column is open
and the two in-line valves in the flow tee below the auxiliary mud container are open,
but the leg of the tee to the mud tank is closed. Mud pumped slowly from a line
connected to the bottom of the reservoir flows up the casing untif all water in the
casing is forced out, and only mud remains. At this time the high-point air-bleed valve
is closed and the mud-tank return-line leg of the tee is opened. With this condition
the system is ready for other operations, such as building of mud cake, impressing of
pressure to begin the equilibration phase, or to maintain pressure during the injection
phase.
During operation, if mud in the simulated wellbore-mud column has been
replaced by water from the flow meter, then the in-line valve on the bottom of the
bottom tee (Figure 4.6, atop the casing-stem that projects from top of artificial
reservoir and below tee on mud-tank return line) must be closed and the valve
adjacent to the check valve must also be closed. When the high-point air-bleed valve
is opened, pressure causes fluid to flow into the line temporarily connected to the
effluent tank. Valves in the mud-line network are adjusted to route mud from the mud
pump to the cross-flow leg of the bottom tee ("Mud Tank Return Line," Figure 4.6).
Mud is pumped until the column is full.
Mud-column Flow Meter
A section of 7-in. casing was used to make the body of the mud-column flow
meter (Figure 4.6, labeled 'Vertical Flow Meter"). This flow meter is mounted
vertically above the artificial reservoir. A Temposonics linear-position transducer
extends from end-to-end in the body. A magnet is attached to a float that indicates
the fluid level; the differential position of the float is calibrated to give flow rate. On
the top of this vessel is a nitrogen line connected to a regulator and high-pressure
nitrogen bottle. Also on the top of this vessel is a fill port for water. The flow meter
monitors the flow rate from the mud column and, for control, also transmits nitrogen
pressure to the column. A nitrogen regulator maintains the set pressure of the mud
column even though the rate of flow varies.
For the case where the injection pressure causes pressure at the reservoir to
become more than the set nitrogen pressure - which is the simulated wellbore
pressure - then mud begins to move up the column until the check valve at the
bottom of the flow meter stops flow and simulates backing-up of a mud column against
4.13
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a cement plug. At this point the injection pressure controls pressure in the wellbore, just
as it would in an actual well.
This simulated wellbore-mud column is very important in simulations of drilling
operations to build mud cake on walls of the reservoir. (Details of this process are set
out on page 4.25, under the title "Simulation of Drilling Process to Build Mud Cake.")
SIMULATED WATER-RESERVOIR ZONE
Introduction
An abandoned well necessarily has gone through a drilling stage and then a
stage of plugging. The simulated condition follows the same steps. First, the reservoir
is filled with water under pressure commensurate with the depth that is being simulated.
Then the drilling is imitated by circulation of mud from bottom to top, past the porous
medium, which is maintained at reservoir pressure. Mud in the column is maintained at
pressure appropriate for depth of the well and density of the mud. This process is
continued until mud cake is developed fully - when there is negligible flow or no flow of
filtrate into the reservoir. In the test this is determined by the flow meter that measures
effluent from the reservoir.
Artificial Reservoir: Function and Construction
Flow is radial from the wellbore into the reservoir; thus a cylindrical section was
used to simulate the reservoir. A medium with permeability and porosity similar to those
of natural reservoir rock is necessary for accurate simulation. Radial, non-converging
planar flow from the wellbore outward is required to be similar to that in a large-volume
reservoir. These conditions were met by pouring a mixture of resin and graded sands
into a cylindrical housing. This process is described in Appendix A; see especially
Figures A5 through A9.
This artificial reservoir was poured in two steps. The first was a 1-in. shell in the
outer periphery of the cylindrical housing. This coarse-grained, highly permeable
synthetic sandstone had very little resistance to flow. The main part of the reservoir is a
vertical-walled cylinder of artificial sandstone with flat top and bottom; the outer walls are
bonded to the outer, highly permeable shell and to the top and bottom flanges of the
steel reservoir housing. This reservoir cylinder must be in the range of permeability of
fresh-water aquifers. Permeability was controlled by compaction of the sandstone. A
large tamping device is used (Figure 4.10), which is programmed to apply pressure at a
given level and to tamp for a given number of cycles; this is done with the hydraulic
pumping unit shown in Figure 4.11.
4.14
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Figure 4.10 The large tamper in position to tamp artificial reservoir.
4.15
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Figure 4.11 Hydraulic pump and controls for large tamper.
4.16
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A borehole in the center of the cylinder is the same size as the casing that
simulates the wellbore. A bonded interface between the top of the reservoir housing
and the rock and the bottom of the housing and the rock is required to insure that flow
does not take a path having permeability different than that of the rock. Because
permeability of the outer shell is much larger than that of the core of the reservoir,
then the axial (vertical) pressure gradient is very small and the driving force comes
from the radial pressure difference between the wellbore and the outer shell.
Therefore, flow should be planar and radial. To assist in maintaining this planar,
radial flow in the core of the artificial reservoir, 24 holes are distributed around the
side walls of the cylinder. This series is shown schematically in Figure 4.6.
An explanation was given above of. how mud pressure in the wellbore is to be
maintained to simulate conditions in the actual well. The artificial-reservoir pressure
must also be maintained, but independently of the mud pressure. In large reservoirs,
at places distant from the borehole, virgin reservoir pressure is maintained until a
large amount of fluid is injected into the reservoir. Because a virgin fresh-water
reservoir is to be simulated in the case at hand, and because pressure of this
reservoir would influence the full development of mud cake, then constant reservoir
pressure must be maintained. Pressure is developed by a nitrogen-filled accumulator
bladder in contact with the effluent water. The nitrogen-pressure regulator maintains
pressure at the desired value, which is just slightly less than the reservoir pressure. A
high-precision pressure-regulated bypass valve is set at the reservoir pressure so that
when, or if, pressure of the core fluid becomes greater than that of the virgin reservoir,
the bypass opens and flow exists, but pressure is maintained. Controls to achieve
this constant reservoir pressure are shown schematically in Figure 4.6.
Artificial-reservoir Housing
The largest feasible artificial reservoir was desired. Expense and handling
operations were the limiting factors. The resultant reservoir housing is 2 ft. high and 3
ft. wide. The housing was constructed to be strong enough to withstand high
pressures, so as to allow simulation of a range of reservoir depths. The housing also
was designed to permit emplacement and replacement of artificial rock, to give the
capability of using a sequence of different reservoirs. The final design used flanges
welded on a 3-ft.-diameter section of pipe with mating modified blind flanges on top
and bottom. With the flanges, the allowable operating pressure is 1450 psi, which
translates to an equivalent depth of about 3000 feet. This pressure required that the
flange bolts be torqued to 2500 foot-lbs. A 5-1/2-in. casing sub was welded in the
center of each of the two modified blind flanges. These subs are to simulate the
borehole and to provide connection to the upper simulated wellbore-mud column and
the lower wellbore. Design drawings and design information are in Appendix A.
4.17
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Associated with this housing is a hose system, to provide a path for fluid forced
out of the reservoir to be directed to the effluent tank (Figure 4.6). These hoses were
sized to insure that the pressure drop attributed to these was much less than the
pressure drop through the reservoir, for the range of flow rates expected in the
reservoir. The number and array of these hoses were designed to give relatively
uniform flow along the side walls of the housing. In addition, positioning of hoses was
to allow placing of a wrench on the flange nuts and to minimize entrapment of air in
the lines. Flexible lines were used to accommodate the compound curvature from row
to row.
In order to minimize path of flow and provide a simulation of drilling, a 2-in. line
for the mud-pump connection is welded to the 51/2-in. casing sub at an angle to the
axial line of the casing and tangent to.the wall of the casing. This causes fluid to take
a spiral path up the casing, to simulate the rotation of drill pipe in the borehole (Figure
4.6, below bottom blind flange).
Another line connection is welded on the lower 51/2-in. casing sub, but above
the mud-pump connection (in Figure 4.6, elliptical dot on casing sub, a few inches
below bottom flange of reservoir housing). This connection is to provide a source of
fluid to run permeability tests. It is above the mud-pump connection, so space is
available between the two to place an inflatable plug in the line; this plug is to keep
the reservoir from being drained when the bull plug on the bottom end of the casing is
removed, in preparation for connection to casing in the hole. The inflatable plug is
removed by the mud's displacing it out the top, to keep from affecting water in the
reservoir. If sufficient deflation of the plug can be accomplished, an alternate removal
method is to pull the plug out slowly with a wire line, to allow replacement of the
displaced volume with water from the upper 51/2-in. casing sub.
Hammer unions in the upper and lower casing subs are required because of
the need to assemble and disassemble in close tolerances without rotating the casing.
Information from this reservoir housing is acquired with differential-pressure
transducers, pressure transducers, temperature sensors and a flow meter. To
determine the pressure gradient across the reservoir in the axial direction, a
differential-pressure transducer was mounted on the casing sub just above the upper
modified blind flange; pressure lines are connected to a diaphragm housing above the
top flange and to one below the bottom flange. Information gained from this
transducer is pressure drop during mud cake buildup, and change in fluid gravity during
static tests and salt-water injection tests.
Three differential-pressure transducers are manifolded, so e?ch can be
isolated when the radial pressure gradient goes out of its range. To maintain good
accuracy at all pressure differences required having one transducer measure from 0
4.18
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to 50 psid, one from 0 to 250 psid and the third from 0 to 1000 psid. Pressure
differences increase as injection pressure increases, and the test can not be shut
down or interrupted to change transducers. These three transducers measure the
pressure from the same diaphragm housing above the top flange to the radial effluent
line. These data, in conjunction with the axial differential pressure, provide the
reservoir radial pressure gradient. This gradient will be used for calculations of
permeability and for correlating the potential invasion flow-rate across mud cake.
A pressure transducer is mounted on the casing sub above the top flange
(Figure 4.6); its purpose is to monitor the mud-column pressure. A temperature
sensor is mounted in the same general position. These two measurements and the
axial pressure gradient define the state of mud in the casing sub.
The effluent line goes to a flow meter (Figure 4.6), which measures from about
0.0005 gallons per hour to about 32 gph. Included with this assembly is a back-
pressure valve that is set to control the back pressure precisely. Adjacent to it is an
accumulator that is operated from a regulated nitrogen bottle, to initialize the reservoir
pressure and adjust to the desired value. From the outlet of the back-pressure valve,
fluid goes to a tank that contains the effluent until it is disposed of properly.
Simulated Reservoir Rock
Actual reservoir material has a large range of permeabilities and porosities. A
single value was chosen for each of these properties for the first test, but the
capability exists to simulate a broad range of values. A detailed account of the
development process to achieve the design requirements is in Appendix A.
Figure A9 shows the reservoir rock in an intermediate stage of the reservoir
development. The dark-colored rock is the highly permeable rock shell that was
discussed above; the light-colored rock was mixed and emplaced to have the
designed porosity and permeability. To obtain the desired rock properties, the sand-
and-resin was tamped by the system shown in Figure 4.10; the pressure and number
of tamps were controlled with a hydraulic pump, and a programmable controller
(Figure 4.11). Of course the cylinder was filled completely with the light-colored
material, which was bonded to the top flange gasket. The central borehole was cored
before the top flange was placed on the cylinder, and after the material was cured.
4.19
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The central core was cut with the large core-boring system shown in Figures
4.12 and 4.13. Core plugs were cut from the central core (Figures 4.14,4.15) for
analysis in the nitrogen permeameter and the Mud-cake and Permeameter System.
Rock Porosity and Permeability Measurements
The porosity-measurement technique begins even before the artificial rock is
placed in the reservoir housing. With the housing completely assembled and a bull
plug on the bottom of the attached 51/2-in. nipple, the void is filled with water by
pouring from a 1000-ml. graduated cylinder. This yields the bulk volume. After the
artificial rock is placed in the reservoir housing, the void space is filled with water from
the peripheral effluent lines, through the salt-water-injection flow-meter assembly.
Knowing the overall dimensions of rock placed into the housing, the two water
volumes and porosity of the coarse rock allow determination of porosity of the
simulated reservoir rock. The coarse outer-shell porosity was determined by Amoco's
tests of porosity (Appendix A).
After the tests are run and the blind flange is removed, the large core-boring
system (Figure 4.12) is attached to the reservoir housing in numerous locations, so
that 2-ft.-long cores can be removed from each desired location near the periphery of
the wellbore. Then plugs are to be taken from the 2-ft. cores and evaluated for
porosity, permeability and mud content (Figures 4.14,4.15).
When the reservoir is full of water, then permeability is measured. The line
from the saltwater-injection flow meter is connected to the 1/2-in. fitting welded to the
5 172-in. casing nipple. The effluent line is connected to the effluent tank. A flow rate
is established by adjusting the pressure differential across the reservoir radius. This
is done by adjusting the back-pressure valve on the effluent line and nitrogen
pressure in the associated bladder. By measuring flow rate, pressures, differential
pressures and temperatures, and by measuring viscosity of the water, permeability
can be calculated.
Measurement of porosity and permeability is discussed under the topic of
Operating Procedures 6.1 and 6.2, Appendix F. After these tests are conducted, the
artificial reservoir housing must be moved, centered over the well, and connected to
the casing string (Figure 4.8). The Assembly Stand (Location A, Figure 4.2) is
designed to make this transition; the four legs have adjustable jacks to provide easy
connection with the casing (without unseating casing from the slips).
4.20
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Figure 4.12 The large core-boring machine on top of artificial reservoir.
4.21
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Figure 4.13 Close-up photograph of large core-boring machine on top of artificial
reservoir.
4.22
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Figure 4.14 The small core-boring machine, cutting plugs from core of artificial
reservoir.
4.23
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Figure 4.15 Close-up photograph of small core-boring machine, with vacuum
system attached.
4.24
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SIMULATION OF DRILLING PROCESS TO BUILD MUD CAKE
During the drilling of a well, pressure on mud that is pumped through the drill
pipe, through the drill bit and up the annulus must be sufficient to move the fluid
against the head pressure and also to overcome friction. Because of this, pressure
during the building of mud cake is higher than static pressure of mud that is
motionless in the wellbore. Initially the reservoir being penetrated has inherent
pressure, then the reservoir is exposed to the stagnation pressure of flowing mud and
then to the flowing static pressure. Sides of the wellbore are subjected to mud at
flowing static pressure over the greatest period of the drilling operations. Thus mud
cake in the test procedures described here is to be developed at flowing static
pressure. This will create pressure differentials to form mud cake that vary with each
reservoir depth in the test series.
A pressure-operated bypass valve is in the mud-line network to prevent over-
pressurization during start-up and operation. Before mud is circulated to build mud
cake, the test-simulated wellbore must be full of mud. Pressure in the reservoir is to
be elevated slowly to equal virgin reservoir pressure, by (a) adjusting the accumulator
pressure in the effluent-flow-meter system, and (b) simultaneously adjusting the
nitrogen regulator in the mud-column flow meter, to make mud-column pressure equal
to reservoir pressure.
/
During this pressure buildup time, valves in the mud flow lines coming from
and returning to the mud tank are closed at the wellbore connections (Figure 4.6).
Concurrently the mud pump circulates mud through the bypass valve, which was pre-
adjusted to a specified increment above the static flowing mud pressure. The back-
pressure valve in the return line from the reservoir must be pre-adjusted to be equal to
the static flowing mud pressure. Then when the valves leading to and from the
wellbore are opened, a surge of mud flows up through the central part of the reservoir
in a swirling fashion, which simulates drilling-fluid dynamics. The pressure differential
between the mud and the reservoir causes mud cake to be built on the porous wall of
the reservoir. How long this process takes is to be judged by observation of flow-
meter output.
To not disturb the mud cake, the shut-down process becomes important While
the mud is circulating, the mud-column pressure source is adjusted to be equal to the
static mud pressure (which is less than the flowing static pressure). Then the back-
pressure valve is adjusted to cause the flowing pressure to be equal to static mud
pressure. At this point, the supply valve is shut off and the bypass valve routes mud
back to the tank. The return line is then shut off and mud is confined to the wellbore
and reservoir system at the appropriate pressure.
4.25
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SIMULATED WELLBORE AND INJECTION ZONE BELOW RESERVOIR
Introduction
Communication from an injection well through a subsurface injection zone has
the potential of mixing salt water with drilling mud and raising pressure considerably in
the mud column. Therefore, to simulate only the direct effect that depth and borehole
volume have on the process is not sufficient. Thus, it was determined to make
possible a range of depths from about 200 ft. feet to 2000 ft. This was accomplished
by drilling the 2100-ft. well, cementing it from bottom to top, and placing a full open
head on the top casing joint with 51/2-in. slips. Casing can be run in the hole to the
desired depth and hung on the casing-head slips. Rather than drilling an adjacent
well and injecting salt water in it, hoping that some of the salt water would get to the
test wellbore, a string of 1 1/4-in. tubing is run on the outside of the 51/2-in. casing
and salt water is supplied directly into the casing at the injection point. A check valve
is in the tubing at the injection point, to supply fluid to the casing, but not to permit
fluid to flow from casing to tubing. Specific design drawings and design information
on tubular materials and components associated with the down-hole part of the facility
are in Appendix B.
Pressure of mud at the injection point is governed by pressure set for the
simulated reservoir section, depth of the casing string in the hole, and density of the
mud. As discussed previously, this pressure can be varied to simulate wells as deep
as 3000 ft. to the upper reservoir, and by adding 2000 ft. of casing down to the
injection point; total well depth that can be simulated is 5000 feet.
Well Configuration
Sixteen-inch-diameter surface casing is set to 333 ft. and cemented bottom-to-
top. The long string, 10 3/4-in. casing, was run to 2100 ft. and cemented bottom-to-
top with light cement.
Screwed to the 10 3/4-in. casing is a 10 3/4-in. to 5 1/2-in. casing head. This is
a full open head to allow all the 5 1/2-in. casing and 1 1/4-in. tubing into the 10 3/4-in.
casing. Slips were modified to allow instrumentation lines and salt-water injection
tubing to pass through while the casing is set in the head. A transition piece was made
to reduce the 1 1/4-in. tubing to 1/2-in. tubing and a 1/4-in. tubing for venting purposes.
In order to simulate any depth between 100 ft and 2000 ft., the 51/2-in. casing
and the 1 1/4-in. tubing are run into the hole simultaneously until the injection point is
reached. At that depth, the casing is set in the head.
4.26
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Measurement and Control
Injection pressure for salt water is supplied by an accumulator with nitrogen in
the bladder and the column head of salt water going to the injection point. The
accumulator forces fluid through a flow meter and into the line that extends to the
injection point. If pressure is sufficiently high, flow results; otherwise the pressure is
statically impressed upon the mud column. A detailed set of drawings and design
information for the flow meter and controls is set out in Appendix B.
In order to determine the mud characteristics and dynamic behavior of the mud
column in the injection area, a sequence of differential-pressure transducers was
placed on the 51/2-in. casing and run down-hole. Strategically placed pressure
transducers and temperature sensors were also placed on the pipe. Considerable
design and search were required to accomplish this task. Original design concepts
were to run each wire from the individual sensor to the top of the borehole, but this
became quite problematic after calculation of dimensions and weights, and review of
the required operations. An application from Oklahoma State's Outer Space research
program solved the problem, through design of a multiplexer that required only one
cable from the surface. Multiple sensors are attached to it from a series of locations
below the multiplexer. The multiplexer can serially select a given sensor and send
that part of the signal up-hole, cycle to the next sensor and repeat the operation until
all sensors are sampled; then the cycle repeats. At the surface a computer program
sorts the data and stores it in an array, for further use. These instruments and
controls are shown in detail in Appendices B and C.
Information from the down-hole jnstruments provides a means of determining
average properties of mud in sections of the pipe defined by pressure connections on
the differential-pressure transducers. The rate of change of these properties should
yield information about dynamics of equilibration in plugged wells and about wells
having injection fluids impinged upon a long mud column. Specific locations of the
instruments are shown in drawings in Appendix B.
Core Plug Development and Testing
Core plugs used in Mud-cake and Permeameter tests are 1 in. in diameter and
1 3/8-in. long. A hydraulic tamping system was designed to provide the necessary
controls and power to tamp the 5-in.-diameter cores of artificial sandstone, from which
core-plugs are cut (Figures 4.16,4.17,4.18). The main components are the frame, a
3-in.-diameter hydraulic cylinder, hydraulic reservoir, hydraulic pump and motor, relief
valve, control valve, flow lines and pressure gauges. A computer program was written
to predict the amount of force on the foot, depending on the pressure-gauge reading.
The quality of cores necessary for experiments requires a consistent tamping
capability; this device provides that.
4.27
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Figure 4.16 Small tamper with 5-in.-diameter core mold.
4.28
-------
Figure 4.17 Small tamper (background), with hydraulic system
and controller (foreground).
4.29
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Figure 4.18 Small core-boring machine.
4.30
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Prior to testing of sets of core-plugs in the Mud-cake and Permeameter
System, permeabilities were measured by a nitrogen-permeameter and a water-
permeameter. The two Ruska permeameters (Figure 4.19) are mounted near the M&P
System; core-plugs are stored in the same area.
Mud-cake and Permeameter System
In the Mud-cake and Permeameter system, nine core plugs of rock can be
tested simultaneously, in a bench-mounted system (Figure 4.20). An instrument panel
is mounted on the permeameter bench for the various conditioning circuits and lead-
lines (Figure 4.21). The system (Figure 4.22) is connected to the mud-mixing and
mud-supply systems by a rather complex network of flow-lines and return-lines (Figure
4.5) The set of lines is used for several purposes; therefore, clear understanding and
ready access to valves is necessary. Most of the 69 valves are outside the EPA
instrument building; to minimize confusion about the locations and functions of valves,
each valve was assigned an index number.
Core plugs analyzed by this system are 1 in. in diameter and 1.375 in. long.
They are emplaced in sleeves of hard rubber and mounted in cylinders that permit the
introduction of water or drilling mud at tops of cylinders. Permeability of rock and rate
of buildup of mud cake can be evaluated by the amount and time-distribution of flow
through the plug. Pressure transducers are installed in the mud-conditioning flow
lines. A set of miniature scales was connected to the data-acquisition system, to
monitor weights of volumes of mud filtrate or drilling mud transmitted through core
plugs (Figure 4.23); weights can be measured as functions of time, to within
approximately one-tenth of a gram. Information from the scales can be transmitted to
the data-recording computer on a real-time basis during operation of the
permeameter.
Samples of drilling mud are obtained from a valve and tube on the incoming
mud line, upstream from the bypass valve. These samples are taken to determine
whether the required mud weights and funnel viscosities have been achieved during
pre-test procedures. Proportions of constituents are varied until the 9 Ib-per-gal. and
36-sec. conditions are met. Then a settling chamber of mud is filled from this sample
tube; also, a gallon of mud is collected for testing of properties. The testing of mud
(Figure 4.24) is to determine these properties: 10-sec. gel strength, 10-min. gel
strength, plastic viscosity, yield point, apparent viscosity, and pH.
4.31
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Figure 4.19 Ruska nitrogen-permeameter (left), and Ruska
water-permeameter (right).
4.32
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w
CO
From Mud Pump.
To Mud Pump-
Flow Bypass Line.
-M & P Permeameter Subass'y
• Back Pressure Valve
Data Acquisition Multiplexer
Temperature Sensor
Drip Photo
Sensor
Data Acquisition
Computer
Figure 4.20 Functional schematic drawing, M & P System.
-------
Figure 4.21 Data-acquisition system for M & P tests, with "AND" scale to right.
4.34
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Figure 4.22 Mud-cake and Permeability test system.
4.35
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Figure 4.23 Close-up photograph, instruments of M & P system, and "OHAUS"
scale (below).
4.36
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Figure 4.24 Mud-properties test station.
4.37
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Because the yield of data from nine core plugs is concurrent, accurate data-
recording by hand is not practical; therefore digital data are recorded on the hard disk
of an IBM-compatible 286 personal computer integral to the system (Figure 4.21).
Software was written for this process and adapted to circuit boards that were
designed and built for multiplexing of signals. Flow of water from bottoms of plugs is
monitored by nine photoelectric cells that detect the formation and release of drops of
mud filtrate (Figure 4.23). The photocells were graded to effectively the same levels
of sensitivity and response. A great deal of experimentation was required to develop
a procedure for regulating flow of water from discharge tubes, in a manner that would
be recorded consistently and accurately by the photocells. For example, core-holder
discharge tubes must be configured so as to form drops and streams of consistent
form and pathway; otherwise, detection by photocells is not consistent. Moreover,
each photocell must be aligned and adjusted so that the sensor does not detect the
accumulating droplet, or so that such detection is minimized. Additionally, consistent
triggering of the circuit required addition of a variable resistor to the circuit.
Systems were tested to eliminate error or to estimate potential error. For
example, the valve in the discharge tube attached to the bottom of the mud cake-and-
permeability core holder separates the upper and lower tubes; only the upper tube is
filled with water prior to the testing. Careful measurement showed that at the
conclusion of a test, 0.3 gram of water is retained in the lower tube. Thus,
considering a test-volume of 30 grams, an expectable error of 1 % occurs simply
because the instrument retains water. A second example has to do with flow of water
through core plugs: if samples of 1-in. diameter are seated directly above a discharge-
hole of 1/4-in. diameter, convergent flow occurs in the core plug. These flow-paths
invalidate the estimates of permeability. This source of error was eliminated by the
milling-out of the basal part of the core-plug holder into a hemispherical form, with
diameter of just a few thousandths of an inch less than diameter of the core.
Software permits the data-file from each photocell to have unique, imbedded
test-identifiers. The array of data includes pressure, total flow, times at which valves
are opened on the core-plug assemblies, times at which incipient flow starts, times at
which flow stops, and times at which valves are closed. In one measurement of flow
rate, sampling interval is approximately 0.2 sec., so vast amounts of data can
accumulate in a brief span of time.
At one stage in evolution of the data-recording subsystem, discrepancies
between'data stored on the hard disk and data detected with an oscilloscope showed
significant differences. The multiplexer cycle and the storage method were too slow
for registry of the complete set of signals. Software was modified so that photocell-
activity was detected if any one cell was activated. Data were saved to the digital file
in hexadecimal format; periodically, analog data were saved on a separate file.
Finally, photocell digital data were saved to the digital file, and digital data from the
4.38
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valve sensors were saved on the analog file. For any given test, this arrangement
leads to capture of all pertinent data.
Gauges mounted in parallel arrangement with pressure transducers permit the
direct reading and hard-disk recording of back-pressure during adjustment of the
back-pressure valve. A thermocouple detects the bulk-flow temperature downstream
from the mud-cake and permeability system. Due to the complexity of the systems -
69 valves, multiple sensors, and two data-storage methods - the number of
operations the system accomplishes and sequencing required to obtain repeatable
data resulted in many versions of the operating procedures (Appendix F, Operating
Procedure 17). Forms were developed for hand-entry of information during the
operation of the system, as more understanding of the system was revealed. Different
parts of the software were utilized, depending on the particular phase of operation in
the mud-cake and permeability tests. These necessarily were detailed, and warnings
were placed so that the software would not terminate prematurely; for example, if the
On-Off button on the scales is depressed instead of the Tare button, the entire system
is shut down and a total restart is required.
MONITORING OF SETTLING OF DRILLING MUD
The effect of change in the type of fluid at the interface of drilling mud and mud
cake is to produce a greater or smaller potential for plugging. If a positive differential
pressure exists, mud cake tends to build with passage of filtrate from borehole to
reservoir. As mud would settle in a well and fractionate to solid-particulate material
below and water above, in the water-column the likelihood of continued plugging with
increase of borehole pressure should diminish - owing to depletion of clay in
suspension. Therefore it is important to evaluate the fundamental characteristics of
mud as a function of time. A simple but effective way to obtain this information is to
place mud that was mixed to specified density and viscosity (Figure 4.24) into
columns (Figure 4.25) that are transparent, seal the tops of the columns to reduce
evaporation, and monitor the levels of water-mud interfaces.
4.39
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02.0"
020"
2888"
01.5"
67.0"
45.28"
Figure 4.25 Dimensions of mud-settling columns, which are made of clear plastic.
4.40
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SECTION 5
INSTRUMENTATION: DESIGN AND APPLICATION
INTRODUCTION
Design of instrumentation includes the design of the system of sensors, the
selection of components and the design of the instrument itself, in some cases. In the
case of flow meters, many hours of searching the literature for various sensors failed
to provide information about instruments that would fit all the criteria. Also, literature
was searched for sources of differential-pressure transducers that had the accuracy,
line-pressure range and small size to satisfy the constraints of the project. These
features will be discussed in this section of the report. Specific design drawings are in
Appendix B.
INSTRUMENTATION DESIGN FEATURES
MULTIPLEXER SYSTEM FOR DOWN-HOLE SENSORS
The multiplexer system for down-hole sensors is developed and debugged.
Problems associated with improper sweeping and storing of signals were solved by
rewriting of the data-acquisition program.
TEMPERATURE SENSORS
Temperature sensors were selected on the basis of accuracy, stability and
signal output. The AD 590 KF temperature sensor was chosen, which yields micro-
current output. Accuracy and linearity were enhanced by designing a circuit to cover
the design range expected in the test series. As designed, accuracy of the sensor is
about 0.3 deg. F.
DIAPHRAGM HOUSING
Three problems or anticipated problems resulted in design of the diaphragm-
seal housing. Small lines connect the pressure transducer to the pressure source.
First, mud in the system potentially would differ significantly with time; therefore we
cannot rely on knowing the properties as a standard. Second, mud may harden in
small lines and affect pressure measurements. Third, if mud and salt water were to
enter a transducer, the transducer would be damaged.
5.1
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During verification of the differential-pressure measurement technique, in
transition from atmospheric pressure to 3000 psi, air in a line compresses to less than
2 percent of original volume. Therefore, air-to-mud interface in an instrument line is
not feasible for high pressures. Further calculations showed that when pressure
increases from atmospheric to 3000 psi, water in 1/4-in. tubing compresses to a
displacement of about 3.5 in. in a 30-ft.-long tube. Circumstances of this kind led to
design of the bellows diaphragm. A Bellofram diaphragm rolls and unrolls in response
to a moving piston; it was chosen to eliminate essentially any resistance to
transmitting pressure, so that measurement could be accurate. The volume of the
half- displacement was selected to be equal to the 3.5-in. displacement in a 1/4-in.
tubing. In this project, the diaphragms were used under movement of drilling mud, in
the absence of a piston, and they were pressed against and into a passage that is
circular in cross-section. The diaphragms were studied for evidence of failure and for
the likelihood of failure under further down-hole testing. Alternate designs of
diaphragms were evaluated but rejected. The bases of rejection were (a) pressures
exerted on diaphragms are to be less than 1500 psi in the tests; (b) flexing of the
rubber is a short-stroke movement, and (c) chambers in which the diaphragms
operate can be modified slightly. In the modified chamber, during unrolling and
rolling, the rubber can assume the form of a piston-driven sleeve and the area
exposed to the circular passage is reduced.
Bellofram diaphragms were tested for effectiveness. They withstood pressures
of 2000 psi; failure was at levels greater than 2000 psi, which exceed the pressures
anticipated to occur during down-hole testing.
The final configuration, shown in Figure B1, is to fit the contour of the pipe,
keep air bubbles from being trapped, fit in the annulus in the well, allow replacement
of the diaphragm, seal the pressure, and adapt to the plumbing requirements.
PRESSURE TRANSDUCERS
A search of commercial pressure-transducer sources revealed that most
designs on the market are not conducive to placement in a small annulus. Among the
several choices, some were eliminated because of extremely long delivery time, some
because of levels of accuracy, and some because of cost. Two types were chosen; a -
Validyne P305A absolute-pressure transducer and an ICSensor 115 pressure
transmitter. More information is in Appendix B.
Each of these transducers was plumbed to the diaphragm housing with 1/4-in.
tubing and fittings so that it could be filled with water, to allow air to bleed from the
lines. These diaphragms were mounted on the casing or on special brackets that
provided communication directly with the fluid being measured. Holes into the cavity
of the diaphragm are configured so that as fluid is being placed in the casing, air is
5.2
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not trapped in the cavity. Also, the surface where holes are drilled will not cause
disconfiguration of the diaphragm seals, due to the differential pressure of instrument
fluid and air in the casing before water or mud is placed in it.
Pressure ranges vary for the different pressure transducers based on potential
locations in the well, maximal reservoir pressure anticipated, maximal injection
pressure and maximal simulated mud-column depth to the upper reservoir. A list of
pressures is in Appendix B, Table B1.
All pressure transducers have been evaluated under calibration tests.
DIFFERENTIAL-PRESSURE TRANSDUCERS
Unlike the pressure transducers, the differential-pressure transducers were
limited to only one choice. Only the Validyne P305D transducer would fit the
accuracy, line-pressure range, (differential-pressure spans, size and configuration
criteria.
The differential-pressure measurements require that two sources of pressure
be tapped into. Thus, a diaphragm housing is required at each location. The
distance between the diaphragm housings and the density of the fluid being measured
dictate the pressure span for each transducer. The maximum pressure expected in
the vertical sources is based on the density of bentonite. A list of pressures
associated with a given differential-pressure transducer is shown in Appendix B,
Table B1.
All instrument lines are configured similar to that discussed for the pressure
transducers, but the high-pressure side of the differential transducer extends down
the casing several feet. Figure G2, Appendix G, shows lengths between the down-
hole differential-pressure transducers. This part of the line acts as a manometer and
is part of the data-reduction equation to find the mud density; therefore density of the
fluid in this line is required.
At one point, each of the transducers is connected to the same pressure source
because the diaphragm seal is large enough to accommodate expansion into each of
the lines. The differential-pressure transducers are coupled one to another, so that
the sum of the pressure drops theoretically should equal the pressure difference
between the pressure transducers at the two extreme ends, as a check in the
readings. The measurements are not expected to be exactly the same because the
pressure transducers measure the full value of the pressure; this results in a different
reading accuracy than for the differential pressures.
5.3
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PISTON FLOW METERS
An extensive search was made to find a flow meter that would measure very
low flows accurately while operating in a high line pressure, and that would extend to
moderate flow rates. Because none could be found to fit the criteria, a flow meter was
designed. Several concepts were reviewed before the final design, which is shown in
Figure B4, Appendix B. The design had to allow for continuous or intermittent flow,
and measure with accuracy flows as small as about 0.0005 gph or as large as about
32 gph. Basically, the method is to know accurately the location of a piston in a
cylinder at a given time and at subsequent times. In order to accomplish this a
Temposonics linear-displacement transducer was inserted into a cylinder. This
transducer reads the position of a magnet that is mounted onto a piston. A seal is
between the shaft and piston and between the piston and cylinder wall. Displacement
volume versus time results in a known flow rate.
To allow continuous flow, fluid moves into one end and out the other with the
piston being the interface. When the piston gets to one end of the cylinder the flow
must reverse rapidly. To accomplish this a set of Vindum three-way, four-position
valves was purchased, which has a valve operating-time of less than 0.1 second. For
the flow-rate range concerned with here, this has negligible effect on accuracy during
turn-around. Both valves are connected to the two ends of the cylinder; one controls
the inlet and one the outlet. Controlling the cycle is done with a circuit that was
designed to operate off the Temposonics position signal. Output of the Temposonics
is sent to the multiplexer and stored on the computer hard disk. Figure B4 is an
assembly drawing of the flow meter. There is one flow meter for effluent flow and one
for injection flow. Photographs of these flow meters-are in Appendix C.
FLOAT FLOW METER
The float flow meter operates in a vertical mode; it does not allow continuous
flow monitoring. When the fluid in it is depleted, then the unit must be deactivated
and refilled with water before placement back into operation. To have this flow meter
in continuous flow is not critical, because the volume of the casing that contains the
meter insures an ample supply of fluid, in most instances. This design is similar to
that of the piston flow meter, but the magnet for the Temposonics is mounted on a
float and water level is measured with time. This unit acts as a pressure source for
the simulated mud column; nitrogen pressure is regulated to ullage above the water in
the vessel. Therefore it supplies the mud column flow potential and measures flow
when it occurs.
Output of this flow meter is also sent to the multiplexer and stored on the
computer hard disk. A photograph of this meter is in Appendix C, Figure C10 (see
upper right-hand part of the photograph).
5.4
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MEASUREMENTS OF PERMEABILITY AND POROSITY
Instrumentation discussed in the previous subsections is applied to define the
parameters necessary to calculate values of permeability and porosity. Pressure
differences, flow rate and temperature are used to determine permeability.
Information from the flow meter is necessary for the volume of liquid required to fill
pores, and temperature and pressure are used to define the state of the fluid.
APPLICATIONS OF INSTRUMENTS
Differential-pressure transducers supply information on mud density;
measurements by temperature sensors at the same positions and knowledge of mud
constituents permit the down-hole characteristics of mud to be determined.
Time history of pressure gradients come from the differential-pressure
transducers; these provide an indication of when mud in a long column equilibrates.
Output of differential-pressure transducers and measurement of local pressure
show the behavior of a column of mud when it is subjected to injection pressure at a
given depth.
Permeability and porosity data derived from these instruments supply a method
of relating test data to field data in similar situations.
For a given formation pressure, formation depth and permeability, flow-meter
data determine the amount of mud that invades a formation prior to the building of an
effective mud cake.
A combination of the instruments provides the data to determine the amount of
fluid, if any, that penetrates a mud cake for given values of injection pressure,
reservoir depth, injection depth, reservoir pressure and permeability.
5.5
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SECTION 6
DATA-ACQUISITION SYSTEM
INTRODUCTION
The data-acquisition system for this project was developed by the OSU
Electronics Research & Development Laboratory. Two tasks were presented for the
data-acquisition system. The first task was to design and develop a system for the
"down-hole" portion of the project. The second task was to develop data acquisition
for the Mud-cake and Permeability test stand.
Design criteria included limitations of size and weight, and a relatively long
distance to the farthest sensor. To make the data-acquisition system miniature was
imperative, as size was limited to less than 2 in. of spacing between down-hole piping.
The data-acquisition system was to be "sandwiched" between the 10 3/4-in. casing
and the 5 1/2-in. casing. Weight factors were a key consideration in development,
because the system was to be attached to the down-hole pipe. Individual wiring to
each of more than 50 sensors - as might be considered in a standard acquisition
system - would have accumulated too much weight in this case. With 100 ft. of
single-shielded twisted wire weighing approximately 2.3 Ib., multiplication of this factor
by the number of sensors (with the farthest one at 2000 ft.) made this method
infeasible. With these limitations in mind, a multiplexing scheme was developed that
provided adequate sampling of each sensor and greatly reduced the size and weight
of the system.
Instruments running constantly can yield voluminous, unwieldy data. A good
data-acquisition system guards against this situation. The system must also act as a
control for particular, potentially hazardous conditions. Because this test system
would not be attended 24 hours a day, the design of the data-acquisition system also
included sorting and storage of data.
6.1
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DOWN-HOLE DATA-ACQUISITION SYSTEM
COMPUTER
The computer is a PC-AT compatible with a 40-megabyte hard disk drive, one -
44-megabyte removable hard disk drive, one 1.2-megabyte 5 1/4-in. floppy disk drive,
and one 1.44-megabyte, 3 1/2-in. floppy disk drive. It has an 8287 mathematics co-
processor and a Phoenix BIOS.
FLOW-METER CONTROLLER
The flow meter provides an analog output of 0 to +10 volts relative to the
position of the sensor inside the flow meter. A method was designed and developed
that would limit and reverse the direction of the flow meter. This method employed a
two-level comparator circuit that compares the relative voltage of the flow-meter
sensor to a limit voltage. The limit voltages are pre-set for each individual flow meter,
with voltage of a few tenths of a volt being set for the lower end, and a limit voltage of
a few tenths of a volt below 10 volts for the higher end. The comparator uses an
operational amplifier configuration for the circuit. As the flow-meter sensor reaches a
limit, voltage from the sensor compares with the limit voltage and drives the operation
amplifier into saturation. This provides a "high" output, which is used as a digital
input to a buffer/inverter circuit. The buffer circuit controls the spool-valve relays,
which in turn control the flow direction of the flow meter. At this point, the relays are
engaged (or disengaged), changing the direction of the flow meter When the flow-
meter sensor reaches the opposite end, the comparator again compares the flow-
meter analog voltage with the limit voltage, and the operation amplifier is driven to a
low state, reversing the condition of the buffer/inverter circuit, and therefore reversing
the flow of the flow meter. The two-stage comparator will remain in a steady state,
regardless of the intermediate analog voltage as the flow meter moves from one end
to the other. Only when the analog voltage compares with the high- or low-limit
voltage will it change the state of the controlling relays.
DATA-ACQUISITION PROCESS
The original intent of the down-hole data-acquisition system was to link three
stations, adding a remote multiplexer to each station. For the recent purposes of
testing, monitoring of the first station was decided upon; therefore a more straight-
forward approach for signal conditioning of the sensors could be made. In addition,
current-development in electronic integrated circuits could be used. The existing
sensors and cabling for down hole remained as designed originally.
The new signal conditioner was contained in a single box that housed the
conditioning circuitry and power supplies for five types of sensors used both down-
6.2
-------
hole and at the surface. The different types of sensors were (a) ICS pressure-
sensors, which provided 4-20 milliampere current output, (b) the AD-590 temperature
sensors, which provided 1 microamp per 0.5°C output, (c) the two Validyne pressure
sensors with voltage outputs of 0-5 volts and 0-10 volts, and (d) the Temposonics
devices on the flow-meter stand, with a 0-10 volt output.
The ICS sensor outputs were converted to 0-10 volts through a fixed resistor
and an AD-620 instrumentation amplifier. Temperature-sensor outputs were
converted to voltage through a bridge network and amplified a gain of 10.9 through
another instrumentation amplifier. High and low outputs of Validyne sensors were
multiplexed and fed through an instrumentation amplifier with a gain of 1.99. Each
multiplexed output went through a final instrumentation amplifier for buffering, and
then through a low-pass filter before being sampled by the ADVANTECH PCL711 12-
bit analog-to-digital converter card inside the computer.
Software was also modified and coded using QuickBasic Version 4.5, which
provided a more straightforward and usable form than the previous code, written in
Microsoft 'C1. Highlights of the software program included real-time display of all
twenty-seven sensors, incorporation of calibration data, selection of time interval
between recording samples, closure of data files except when recording, and new files
starting automatically at midnight. In addition, the data were split into two files, one
for down-hole data, the other for data recorded at the surface. Data files are saved as
"DATA.T111 (for "topside" data) and "DATA.D1" (for down-hole data), with the numeral
"1" representing the day of the file. This number incremented with each new file
created at the beginning of a new day. Data are saved as comma-delimited entities,
with a time-stamp for each data sample, and a closing header with date-stamp at the
end of the file. Data files can be imported with the more common types of
spreadsheet software. A listing of the program is in Appendix N, Attachment 1.
MUD-CAKE AND PERMEABILITY DATA-ACQUISITION SYSTEM
The data-acquisition package for the M & P test stand was a unique-system
task to monitor a variety of sensor inputs.
These sensors include:
Power
Description Requirement Output
50-psi & 500-psi
Pressure Transducers +28 volt 4-20 ma.
AD590 Temperature
Sensors (3 ea.) +5 volt 1 microamp./0.5°C
6.3
-------
Thermocouple (1 ea.) 1 10 VAC 4.20 ma
Drip Detectors (9 ea.) +5 VOlt o-5v
Valve Switches (3 ea. ) +5 volt 0-5v
Weight Scales (2 ea. ) 11 0 VAC RS232
h,,i.f «£* T'th '!!•?• down-hole acquisition system, the M&P system required a custom-
anlSt?n^ir;9 netWOhU° ""^ a" Sensor ***** into a "sable *™ *°r
analog input to the data-acquisition board inside the computer In addition a detector
^developed to monitor the flow of water from each of the nine drip tubes T^Se
sSo of tho^'f t1 °f ? infrared emitter and a detector- "*** were placed on Sher
f^iJJ? °TtUbe W'th the Water drlp fallln9 between them- The change in ligh
level when a drip was detected caused a fluctuation in voltage output of the infrared
Wassensed * a buff«r inside the signa*.
outoHho fr se e sgna o
v^£ll * bf?K t0.2° fr°m a hlgh to a low state- The sensitivity for ad usting the
voltage output of the infrared sensor was accomplished by a 1 -kilohm potent ometer
which was set at the voltage threshold of the buffer. potentiometer,
Advantch i^SIS^1^!?" SySt6m *" a "PC"-based computer with an
we^as a?aroo^nn ,t frn f aCqUI?' tIOn carl This provjded dj9|tal input/output as
Ou rkLc^ 29c P»K °m the SI9nal ""dWon^- Software was developed using
2S5 K '5 W'th S°me drivers provided with the M"'t»ab card. In addition iwo
senal ports were needed to accommodate the RS-232 data from the scales
MUD-CAKE AND PERMEABILITY SOFTWARE
th» Hn Ihf6 S°?ware Pr°9ram started with a routine to set up the data files and define
samo e from h^T9 "H** ln additi°n' there Js an option to record a weighed
sample from the scale and save to disk, or to start the program Three data files
*"" ** """ fi'e name but Wlth djfferen*
created
"data".ana (for analog data)
"data".dig (for drip-tube data saved as digital data)
"data".sca (for scale data)
ith a header and date
6.4
-------
When tart Program is selected, the nine drip detectors are the first to be
sampled. Each detector is sampled at a rate ten times faster than that of the analog
data, in order to detect individual drips. (This period is approximately 10 samples per
second). The value of the nine detectors, along with the valve switch positions, is
converted into a hexadecimal number and saved with a time-stamp, in the ".dig" file.
In order to save disk space, data are not saved when there is no activity in all the drip
tubes.
The six analog sensors (pressure and temperature) and the "OHAUS" scale
are then sampled, converted to their respective units of measure (psi, 0.5°F, or
grams), offset with the calibration information and saved to the ".ana" file. The time
between samples for the analog data is approximately 2 seconds. (Communicating
with the RS-232 serial ports of the scales causes some delay).
Another feature is a "watchdog" monitor for the pressure sensors. If the
pressure of either sensor exceeds a set limit, the computer will sound an alarm and
flash a warning on the monitor when pressure is out of limits.
The program continues in a loop until the "ESC" key is pressed. The program is
then aborted, heading information and date stamps are put on each of the data files,
and the files are closed automatically.
Other features include the option to run the scale routine without being in the
data-acquisition program, and re-zeroing the scales from the computer. Data files are
saved as comma- delimited files, which can be imported by any commercial
spreadsheet package
A noteworthy comment about the digital data file ".dig": As mentioned, this file
is saved as a hexadecimal value in order to reduce disk space and to conserve speed
in writing to the data disk. A smoothing program, DELTAST.bas, was written, which
converts the hexadecimal values into readable binary values, with a "1" meaning the
sensor was detecting a drip or flow, and a "0" meaning no activity. A listing of this is in
Appendix N, attachments.
A running average program was also written for the analog data, AVGLbas,
which averages twenty samples of data into one data point. This was used as a
means to reduce data-file size. Another program, AVG1-H.BAS is also used to reduce
the size of very large programs. Both of these programs are listed in Appendix N,
Attachments 6 and 7.
All the software programs developed for use on this project are discussed in
Appendix N. Other software packages used for data reduction were EXCEL and
QUATTRO PRO.
6.5
-------
SECTION 7
RESULTS OF TESTS
SIMULATED INJECTION SYSTEM TESTS
SUMMARY, TEST-TABLE VARIABLES, SIMULATED INJECTION SYSTEM TESTS
Data related to the Simulated Injection System tests are in Tables H11 and L1
and are discussed in the Mud-cake and Permeability test material of this section; also
data are in Table M2, Appendix M.
Table J1 contains data from the artificial reservoir data-acquisition system.
The data show permeability that was calculated from the radial Darcy equation. This
calculation involves the borehole radius, outer radius of the reservoir, temperature of
the effluent - to determine viscosity — flow rate from the BPC flow-meter, data
associated with computer time, and differential pressure from the 50-psid differential
pressure transducer. The table covers eight days of tests.
POROSITY OF ARTIFICIAL RESERVOIR
Reservoir porosity is determined by two methods. One method is to core the
reservoir with a 5-inch bore, drill plugs from the 5-in.-wide core, and measure porosity
of the plugs. Porosity data compiled by this technique are discussed in Appendix M.
An average porosity of 18.75 % was calculated using 85 core plugs from the artificial
reservoir. This average porosity is consistent with other artificial-core data with
similar nitrogen permeability values.
The second method of determining porosity is to measure the amount of water
placed in the core and apply this measurement in an equation related to the total
volume of the reservoir. Water was metered into the reservoir with the SIS flow meter.
Once water reached a predefined level in the casing above the reservoir, the valve
assembly was connected with a hammer union. A vacuum bottle-and-pump system
was connected to the valve assembly and reservoir pressure was reduced to about
726 mm Hg. This process extended over four days. The water that came out of the
reservoir while pulling a vacuum was stored, weighed and returned to the reservoir
while it was under vacuum. The total amount of water removed was 15,968 grams.
This amount plus an additional 13,071.9 grams of water were placed in the reservoir
housing after removing the vacuum and adding water over a two-day period. The
7.1
-------
original water placed in the housing was 77,831.3 grams. Adding the two volumes
and converting it to gallons resulted in a total of 24.017 gallons. Prior to placing any
core material in the artificial reservoir housing, the volume of water that the system
could hold to the same predefined level was 104.2 gallons. The volume of the shell in
the housing is
Vshen=(7t/4)((36.0-1.5)2-(36.0-1.5-2.0)2)(24.116)= 2538 in3 =10.987 gal.
and that of the reservoir rock encompassed by the shell is
V,«= (it/4)((36.0-1.5-2.0)2-(5)2)(24.116)= 19,532 in3 = 84.55 gal.
From analyses by Amoco, porosity of the shell is regarded as being 34.5%;
thus the solid portion of the shell is (1.0-0.345)(10.987 gal). Also the solid portion of
the reservoir is represented by (1.0 - )(84.55 gal). The remainder of the volume
theoretically would be filled with water. Thus the total reservoir-housing volume is
equal to the shell solid-volume, the reservoir solid-volume and the water in the
reservoir. This is represented numerically by
104.2gal = (1.0-0.345)(10.987 gal) + (1.0 - 4>)(84.55 gal) + 24.017 gal.
Solving this equation algebraically for 4> and resolving the value yields porosity of
13.67%.
The first method of estimating porosity of the SIS artificial reservoir gave a
value of 18.75 %, whereas the second method produced an estimate of 13.67 %. The
difference probably is due to voids not filled by water, despite the fact that the
reservoir was under vacuum.
PERMEABILITY OF ARTIFICIAL RESERVOIR
Data were collected to compute permeability to water, mud-cake-buildup
permeability, mud-settling permeability and injection-effective permeability.
Permeability to water was calculated from data obtained while flowing water from
the inside of the reservoir to the reservoir periphery. Pressure was provided by the
nitrogen blanket on the vertical flow meter. After reducing the computer data, average
water permeability was determined as 159 to 161 md; but after differential pressure
was corrected, the differential was only 1.51 psid. In comparison, the M & P test data
(Table H11.1; H11.2) show that permeability ranges from 400 md to 900 md at a
differential pressure of 28.7 psid. Also, data from tests by K & A Laboratories show
(Figure 12) that for rocks with similar porosity, permeability is greater than
permeabilities recorded in Table H11.2. As a result, the bulk-reservoir water-
7.2
-------
permeability data are considered not to be valid for comparison with measurements of
permeability from the other sources.
During mud-cake buildup in the artificial reservoir, the back-pressure control
valves were not suitable for controlling the back pressure that was desired. Also, the
mud-pump packing would not maintain a seal. The final result was that the data were
not sufficiently stable to allow calculations of permeability. Visually observing the drips
from the effluent line and the associated pressures was sufficient to affirm the fact that
mud cake was being established.
Reservoir pressure was being maintained while casing pressure was being
regulated, so that effluent was displaced from the reservoir while the mud-settling
phase of the process took place. Figure 7.0 shows a time interval of the data results
for day 3 of an 8-day time period of settling. Clearly, the instantaneous data were
varied, but they are sufficiently stable to be considered reliable. Table J1 lists the
average permeabilities to specified time periods during these days, and the results are
similar in four of nine values listed in Table H11.5. A general trend from the beginning
to the end of the 8-day data is reduction of permeability. Note that the pressure
differential was generally increasing during this time.
Measurement of permeability during injection of fluid into the casing at about 177
ft. below the reservoir was planned. The reservoir was sampled during the 8-day
period. Mud withdrawn with a large hypodermic sample tube was tested at 8.5 Ib./gal.;
the mud column was not settled enough for it to respond in a manner similar to that of
an abandoned well. The system continued to compile data for 45 days. The effluent
valve was closed to confine the fluid until the system settled sufficiently to begin tests.
Before sufficient settling occurred an electrical storm caused all instruments to quit
functioning. In addition, the computer was on a surge protector; the protector was
destroyed. The computer would operate, but with intermittent problems. Before this
event it was noticed that some of the down-hole pressure transducers were not sensing
reasonable values for the application; some data were even negative values.
Corresponding with this was the fact that fluid was added to the SIS tank continually, in
order to maintain the designed mud-column pressure. Initially a few small leaks were
detected in equipment at the surface and were eliminated. Because fluid was
continually being lost, and because all leaks at the surface were stopped, then down-
hole leaks were the only explanation. Because some pressure transducers were not
reading property, it is suspected that the leaks were in the diaphragms, which were to
isolate transducers from the mud but transmit pressure to water in lines connected to
the pressure transducers. With the given situation the test was aborted. Funds and
time were not sufficient to pull the casing, repair or replace the instruments, and do
associated work required to perform a full-scale injection test.
7.3
-------
1 1
09 •
- 08 -
|07 -
= 0.6 •
S 0.5 •
| 04 -
o 0.3 -
3 0.2 -
0.1 -
-ptzR n n n .n R m n i n n-R m n r
3>n,i nfi.p. nnn.rri..nnr. ,nln, nAn. ,n n cun.. n,
22
21.5
21 !
20.5 ^
2° |
19.5 £
- !
18.5
Time
• Calc Perm (md)
50 PSID
Figure 7.0 Pressure and permeability history, SIS artificial reservoir, 06:21 to 07:40,
12 December 1994.
7.4
-------
MUD-CAKE AND PERMEABILITY TESTS
SUMMARY, TEST-TABLE VARIABLES; MUD-CAKE AND PERMEABILITY TESTS
Some core plugs analyzed by the M&P system were of natural sandstone;
others were made from mixtures of resin and sands, as discussed in Section 4.
Artificial cores were made in multiple batches with a given mixture of materials and
prescribed tamping procedures. A large number of these cores were tested to
determine permeability to gas. Permeabilities of some core plugs were too great to be
measurable by the Ruska gas pemneameter. Others were too "tight" to be useful.
Several hundred analyses were recorded in a Quattro-Pro spreadsheet file and sorted
with respect to increasing permeability. From this sorted list the core plugs were
bracketed in ranges of permeability, so that at least nine plugs were grouped within
plus-or-minus 4 percent of a mean value. The. set of core plugs with mean
permeability of about 2 darcies was large enough for selection of matched subsets.
The set of plugs in the 0.5-darcy range were relatively few, so that the desired range
of permeability could not be achieved. Core plugs were extracted from large
specimens of several formations of natural sandstone; sets of plugs from locations
only a few inches apart varied markedly in permeability. These plugs were sorted
according to rock-stratigraphic unit, and were selected so that the distribution of
permeability was best-fit for the test plan. Tables H1 through H11 (Appendix H)
contain information about sources of core plugs, specific core-plug identification
numbers, core-plug lengths, and cross-sectional areas.
Three phases of tests were run on each set of cores: one to obtain permeability
to water (listed as (H20) in the first section of each table), the second to obtain
effective permeability during mud-cake buildup (listed as (MCB) in the second section
of each table), and last, the in-situ tests - which included replacement of mud in the
system by water, without removal of mud-cake on the core plugs. In-situ tests are
reported as "INS," in the final section of each table. Each table is organized in this
fashion, but not all tables show the same numbers of H2O, MCB or INS tests for a
given set of core plugs. Additions to the basic tests were done to satisfy ad-hoc
questions based upon situations observed during a given test, or to test the effect of
pressure on a given set of core plugs and drilling mud.
These same tables contain fluid-property information, associated with data used
to obtain liquid-permeability. Pressure for all core plugs in a given M&P test was from a
common source; thus imposing the same average pressure on each of the nine cores.
This pressure differs for the different phases within a test and is recorded
appropriately. The value reported in a table is the average of the instantaneous
pressures during the specific time interval of the test phase (for example, see Table
1.4, columns 5 and 6). These pressures are converted to atmospheres in the
equation for calculating permeability.
7.5
-------
Another fluid property has to do with temperature of the system. Temperature
is obtained from a probe in the stream of mud and recorded for use in determining
viscosity, which is one of the variables in computation of permeability of core plugs
during mud-cake buildup (MCB). On each of the three M&P subassemblies (Figure
4.20) embedded temperature sensors are used in determining viscosity of liquid in the
two static fluid tests, H2O and INS. M&P test-identification numbers are listed in
Tables H1 through Table H11, Appendix H. In M&P subassembly one, which is
closest to the mud-pump output, core-plug cells are designated as 1.1, 1.2 and 1.3;
the temperature recorded as T1 is associated with each of these. Similarly, T2 is
associated with core-plug cells 2.1, 2.2, and 2.3 and T3 with 3.1, 3.2, and 3.3. T1, T2
and T3 are averaged and recorded in their respective columns. Viscosity is
determined from these measurements and recorded appropriately.
The equation for computing permeability requires the volume of liquid in cubic
centimeters. Volumes were determined by collecting effluent in beakers and
recording the weights. There are three sets of nine beakers, of 100-ml, 200-ml and
400-ml capacities. Each set of nine is dedicated to one three-cell M&P subassembly.
Each beaker is numbered, 1.1,1.2,1.3 and so on, through 3.3 in each set. Each
beaker is weighed dry and empty, on a scale that is accurate to 0.1 gram. After
collecting the effluent during a single test-phase, the wet-weight of the beaker is
obtained on the same scales. Wet-weight minus dry-weight is recorded in the
summary table and used directly in the equation for computing permeability. (Density
of effluent was checked several times; the true density can be considered as 1 gram
per cubic centimeter.) During operation of the test, the scale used to obtain weight of
effluent from sensor number nine was used to measure weights of all beakers.
At the end of each table are comments pertaining to observations made during
the tests - observations that could have influenced the interpretation of the tests. For
example, the sensors that detect drips would sometimes have water splashed on them
during a test; this caused them to be "stuck on," which gave erroneous readings.
Comments to the effect of having detected this condition or some similar condition,
and having taken appropriate remedial action were quite useful.
Directly or indirectly, all data in Tables H1 through H11 relate to computations
of liquid-permeability. These numbers can be compared, to indicate the effective flow
in core plugs, under varied conditions. Computed liquid-permeability provides a
measure of plugging. For a given pressure, the lower the liquid-permeability, the
closer the core is to being absolutely plugged.
Permeability to nitrogen also is listed in Tables H1 through H11. Gas-
permeabilities of core plugs were obtained using a Ruska permeameter prior to the
plugs' being exposed to water or drilling mud.
7.6
-------
PROPERTIES OF DRILLING MUD
Physical properties of drilling mud are important variables in determining the
effect of mud on plugging. These properties were maintained as nearly constant
during the series of tests. A summary of mud-property data is in Appendix L, Table
L1. Values in this table were obtained using equipment and techniques outlined in
Section 4. Test-to-test comparison of mud properties showed that variation was within
acceptable limits.
LIQUID-PERMEABILITY AND GAS-PERMEABILITY
Comparisons of Permeability
In the ideal circumstance, liquid-permeability and gas-permeability of rock
could be expected to be equal. Tables H1 through H11 show that the two estimates
of permeability differ a great deal. For example, in Table H7 core-plugs of artificial
sandstone are shown as having a nominal value of 1250 md of gas-permeability.
During water-permeability tests an attempt was made to transmit about 200 ml of fluid
through each core plug. Passage of 200 ml required much more time for some core
plugs, directly indicating comparatively low permeability. In Table H7.1, the core plug
in cell 2.2 shows 310.88 seconds run-time, whereas that of cell 2.3 was only 48.39
seconds. The gas- and liquid-permeabilities of core plugs tested in cell 2.2 were 1250
md and 213 md, respectively - the latter an indicator of the long run-time (Table
H7.2). In comparison, gas- and liquid-permeabilities of the core plug in cell 2.3 were
1240 md and 1292 md, respectively. These measurements show that no obstruction
was formed in the latter core; this is supported by the between-drip-time data, which
show that flow was continuous during the test
Data plotted from Table H7 are shown in Figure 7.1. This diagram is an
example of a relatively good correspondence between nitrogen-permeability values
and the water-permeability values. These values are for tests on nine artificial cores
with a nominal nitrogen-permeability of 1250 md. Eight of the nine values are
acceptable data. One of the nine is significantly the lowest; this core (designated
M&P 2.2) was reported to "drip" slowly with respect to the others. The average water-
permeability of the acceptable data, shown in Figure 7.1, is about 1200 md, which is
still lower than gas-permeability. In many of the other test-runs, water-permeability
ranges from about 25% to 100% of nitrogen-permeability. The most probable cause
of the lower water-permeability is fine particulate material in or on the cores. "Fines"
are suspected to have come from several sources: of course, the natural sandstones
contain clay, and in the boring and trimming of all core plugs, small particles tend to
lodge in near-surface pores.
7.7
-------
£
fe
i
1400 •
1200
1000
800
600 4
400
200
1180 1200 1220 1240 1260
Nitrogen Permeability (md)
1280
1300
5/24/94 - 1250 md Artificial
Least Squares Fit
Figure 7.1 Water-permeability as a function of nitrogen-permeability, core group
5/24/94; 1250 md, artificial sandstone.
7.8
-------
Testing with the M&P system begins with emplacement of water in the system,
under pressure, for measurement of permeability. Then drilling mud is circulated
through the system, and permeability is measured while mud cake is built. Finally the
in-srtu fluid (water) is emplaced in the system, and permeability is measured across
mud cake. This process results in markedly different measurements of effective
permeability. The fines within the cores and clay of the mud begin to plug pore
throats to different degrees. As seen along the X-axis in Figure 7.2, water-
permeability of one core plug of the set of nine is considerably distant from the duster
of the remaining eight Permeability during mud-cake buildup (black squares) of this
one core is greater than that of the core with the next-highest water permeability
(approximately 1100 md). Thus, the effect of mud-cake buildup (MCB) on the cores
resulted in similar values of liquid-permeability (whrte squares; see Y-axis) even
though the water-permeability of the one core plug was only about 10% of that of the
other.
Sensors in the system detect the flow- or no-flow condition during tests. Data
from sensors are evaluated to show the time that elapses between drips (the no-flow
condition) and flow time (a period of continuous flow).' When time between drips is
recorded as "O," flow is continuous. As the time-values become larger, the rate of flow
reduces. Figures 7.3 and 7.4 show that intermittent flow and possibly some
continuous flow (see "spike" at 464 sec., Figure 7.4) occurred during a test on a core
in M&P cell 2.2. Figure 7.3 shows evidence of many drips, in the form of numerous
points on the graph; each point records the time-lapse between drips. In contrast, in a
set of reduced data from the core tested simultaneously in M&P cell 2.3 no points
were recorded for the time between drips and only one point for flow-time, because
water was transmitted continuously. Figure 7.4 indicates that flow from M&P cell 2.2
was continuous for more than 200 seconds (or perhaps the sensor was responding to
water splashed on it - a false signal). Sensors were'monitored to see if water droplets
accumulated on them; wiping them dry would correct the recording of false data
points. The core described in Figure 7.4 is the deviant sample described in Figure 7.2
(water-permeability of 213 md). After the run this core plug was removed from the
core holder and inspected; particles of mud were found on the face of the core The
provisional explanation is that mud came from the end of the nitrogen-pressure line
which is directly above the core holder, at the time when the system was pressurized.
The mud got in the line from the previous mud-buildup test, and was not detected.
Therefore, properties of the core plug were not represented correctly, because
particles of mud retarded the flow-rate. This core was cleaned and replaced in the
core holder; upside-down. Another test was started but was discontinued, because
the core still exhibited the slow rate of flow. Cleaning of the surface and reorientation
of the core plug did not alter the partial plugging. The conclusion drawn from these
observations is that relatively small amounts of mud make a significant difference in
permeability.
7.9
-------
9- °-5T
1 0.45
7T 0.4
s 0.35
I 0.3
S 0.25
I 0.2
£ 0.15
S- 0.05 •
J oJ-
200 400 600 800 1000
Water Permeability (md)
1200
1400
5/24/94 MCB
5/26/94 INS
Figure 7.2 Mud-cake buildup and in-situ permeability as a function of water-
permeability, core group 5/24/94; 1250 md, artificial sandstone.
7.10
-------
u
o>
Si-
m
OL
O
o>
1
£
0>
p
1
0.9
0.8
0.7
0.6
0.5
0.4
0.3
0.2
0.1
0
to
a>
o>
CM m co
o> ^ T—
CNl
O ? T-
C«4 CM CM
CO
eo
in o
CM .X
CM O>
O CM
o> m
t- h-
co
r^ o> co
T «> ^
I*.
co
R!
CM CM
s
o
u>
Time (sec)
Figure 7.3 Duration and frequency of time between effluent flow, flow-sensor M&P
2.2, water-permeability test of 5/24/94; 1250 md artificial sandstone.
7.11
-------
250
_ 200
«
0
150
100
50
CMCM
-------
Another approach to verifying the permeability shown for the core in M&P cell
2.2 (Figure 7.1) was to find a test sample with a similar value of permeability, for
comparison. In Table H9.2 the core recorded as M&P 1.2 has water-permeability of
300 md; the core plug is from a set of samples of Pony Creek sandstone, the average
permeability of which is about 1250 md. Figure 7.5 is a plot of the time between drips
for the core in M&P cell 1.2, which is useful for comparison with Figure 7.3. The two
graphs are similar, as one would expect from records of rocks with similar
permeability. The average time between drips of both samples is near 0.1 seconds,
which confirms the permeability of 213 md for the anomalous sample shown in Figure
7.2. Figure 7.6 shows evidence of the correspondence between the time between
drips and permeability. For the core described in Table H9.2, M&P cell 3.2, average
time between drips is approximately 0.48 seconds. This core has water-permeability
of 75 md. Average time between drips of the Pony Creek sample evaluated in M&P
cell 1.2 approximately 0.12 sec.; the core plug has water-permeability of 300 md.
Time between drips is inversely proportional to flow rate and flow rate is proportional
to permeability. The inverse ratio of time between drips is 4 (ratio of 0.48 sec./0.12
sec.) and the corresponding permeability ratio is also 4 (ratio of 300 md./75 md); this
relation is an example of the useful correlation the two sources of data.
Relationship of Nitrogen-Permeability and Water-Permeability
All core plugs were vacuum-cleaned prior to nitrogen-permeability tests. Core
plugs were placed under vacuum in a water bath, to fill the pores before water-
permeability tests. All cores of natural or artificial sandstone used for mud-cake and
permeability tests were selected from a large number of cores, to obtain nine sets of
cores having nearly the same nitrogen-permeabilities. Core plugs selected from the
large core that was cut from the SIS artificial reservoir were chosen for the purpose of
obtaining a core plug from each lift emplaced in the reservoir housing. Selection was
designed to yield measurement of the average nitrogen-permeability of each lift.
Water-permeability of each core plug is plotted against nitrogen-permeability (Figure
7.7). Of the eleven sets of data plotted, ten are sets of analyses based on mud-cake
and permeameter tests of core plugs from natural sandstone and core plugs of
artificial sandstone, drilled from cores of 5-in. diameter. The set designated as
11/16/94 is based on M&P analysis of core plugs from the central core of the large
artificial-sandstone reservoir used for the SIS test. With the exception of the sample
from the SIS test, sets of samples are clustered relatively tightly with respect to
nitrogen-permeability. In the range of lower values of water-permeability, absolute
values are relatively close, but clearly the scatter increases in the higher
measurements of water-permeability. Conversely, the set of samples from the SIS
reservoir show comparatively small variation with respect to water-permeability (they
are almost linear), but large variation relative to nitrogen-permeability. Superimposed
on the figure are four lines, which represent four constant ratios of nitrogen-
permeability to water-permeability: 0.25, 0.50, 0.75 and 1.00. Ideally the points
7.13
-------
mino>o>o>(DO>r«'i>»T-
(D O in (D IO O O CD T™ 00 O
IO O) CO CO O& ^1° f^* O) C^ CO CD
^^ ^^ ^ft ^IP fp ^^ ^^ ^^ QQ QQ QQ
cococococococococococo
CO
«
CO CO O> O> O>
CO CO CO CO CO
r^ »o
W T-'
CM *- '«-
O "* CM
f ^-
Time (sec)
Figure 7.5 Duration and frequency of time between effluent flow, flow-sensor M&P
1.1, water-permeability test of 6/7/94; 1250 md, Pony Creek sandstone.
7.14
-------
331.36
351.36 371.36 391.36
Time (sec)
411.36
431.36
Flow Sensor M&P 1.2
Flow Sensor M&P 3.2
Figure 7.6 Duration and frequency of time between effluent flow, flow-sensor M&P 1.2
and flow sensor M&P 3.2, water-permeability test of 6/7/94; 1250 md, Pony
Creek sandstone.
7.15
-------
2500
o>
2000
•O
£ 1500
1
1000 --
500
,-t
1000 1500 2000
Nitrogen Permeability (md)
2500
. I
3000
12/4/93
5/18/94
11/18/94
3/7/94 —*— 4/27/94 —o— 5/3/94
-•— 5/24/94 —o— e/1/94 —x— 6/7/94
N2/H20=1.0 N2/H20=0.75 N2/H20=0.5
-—*— 5/11/94
—* — 6/21/94
N2/H20=0.25
Figure 7.7 Comparison of water-permeability versus nitrogen-permeability for all tests.
-------
should all lie on the 1.00 line, but they do not, because pore throats were occluded.
Note that the four sets of data plotted between 0.0 and 500 md nitrogen-permeability
seem to fit the 0.25 or 0.5 line; three of the four sets are from core plugs of natural
sandstone. These data show that for "tighter" cores, water-permeability is only 25% to
50% as great as permeability might be - i.e., permeability to gas. Eight of the nine
data-points from the M&P test of 5/24/94 are near the 1.0 line; the data plot at
essentially the average nitrogen-permeability of the set of natural-sandstone samples
dated 6/7/94 -1250 md. However, the data of 6/7/94 are centered closer to the 0.75
N2/H20 line. The general expectation is that in most cases natural sandstone would
have lower water-permeability, because of the greater likelihood of expansive day in
pore throats.
Effects of Pressure on Permeability
During two mud-cake and permeability test series there were periods of time
when pressure was placed on mud in the core subassemblies - after the mud-cake-
buildup phase had been stopped and before the in-situ tests began. These sets of
tests are referred to as "mud-shut-in tests" and during these tests, the fluid chambers
above core-plug holders were occupied by mud cake and drilling mud. Figure 7.8
demonstrates the effects of pressure on permeability during two series of mud-cake
buildup followed by a period of mud-shut-in at a lower pressure. During the mud-cake
-buildup period of the lower pressure (50 psig) variation of liquid permeabilities was
considerable; the average of liquid permeability was the greatest of the three
averages (Figure 7.8). When the back pressure was increased to introduce pressure
of 90 psig during mud-cake buildup, variation in liquid permeability was reduced, as
was average permeability (Figure 7.8). This would indicate that liquid permeability is
inversely proportional to pressure. After the flow was stopped and the sub-section
valves closed, pressure was reduced to an average of 29.3 psig; then flow from the
M&P system was allowed to continue for a period of time. The resulting average
liquid permeability (Figure 7.8) was less than the other two averages, a fact that tends
to contradict the inverse permeability-to-pressure trend described above. One trend
that was maintained in this three-part sequence was reduction in variation of liquid
permeability, as considered on an absolute basis. This explanation is suggested for
the apparent contradiction in the pressure-to-liquid permeability relationship: After
increase in pressure from 50 psig to 90 psig, mud cake was in place. Although the
pressure was reduced to 29.3 psig, a positive pressure-differential across mud cake
still existed, and filtrate continued to move through the mud cake. Therefore accretion
of mud cake continued, with concomitant decrease of permeability.
Another mud-shut-in series was conducted during tests on Bamsdall
sandstone; additional evidence of the trend of liquid permeability's being inversely
proportional to pressure was recorded (Figure 7.9). An important note is that the
mud-cake buildup pressure prior to the mud-shut-in tests was at an average of 50.2
psig. Also the average mud-cake buildup permeability was 0.112 md prior to the
7.17
-------
025 T
S"
£ 0.2 -
£
Jo,.
I 01 •
1 005 -
500
1,000 1,500
Water Permeability (md)
2.000
2,500
MS\ 29.3 psi
MCB 50 psi
MCB 90 psi
Figure 7.8 Effects of pressure on permeability, mud-cake buildup and shut-in
conditions, measured on core group 4/27/94; 2000 md, artificial
sandstone.
7.18
-------
_ 0.35
•o
E. 03
| 0.25
I °'2
I 0.15
S.
5
01
0.05
0
20 40 60 80 100
Water Permeability (md)
120
140
160
} psi —
•a MSI
14.
5 _.-,, _
MSI
34
8
psi -
°- MCB
Figure 7.9 Effects of pressure on permeability, mud-cake buildup and shut-in
conditions, core group 12/7/93; 500 md, Bamsdall sandstone.
7.19
-------
shut-in teSts (Figure 7.9) The increase of liquid permeability from (relatively) high
mud-cake buildup pressure to lower mud-shut-in pressure is consistent with inverse
variation of permeability with pressure. Figure 7.9 shows that as pressure was
increased from 4.9 psig to 34.8 psig permeability was reduced and variation of
permeability from core to core decreased considerably. Each pressure change shown
in Figure 7.9 coincided with the trend; MCB 50 psi test to MS! 4.9 psi resulted in an
increase in permeability, MSI 4.9 psi to MS114.5 psi resulted in a decease in
permeability, and MS114.5 psi to MSI 34.8 psi also resulted in a decrease in
permeability.
After the mud-shut-in (MSI) period of testing was completed, then mud in the
chamber above core plugs was replaced with water, without removing the mud cake.
This procedure was done two ways; in the earlier tests water was drained from the
subassemblies, which had been isolated. In the later tests mud was replaced by
washing the supply tank and flushing the transportation lines, through the M&P
bypass line. Effluent was put in the effluent tank. The bypass line was closed and
water was run slowly through the M&P system,'replacing mud with water. Figure 7.10
illustrates the result of in-sftu tests that followed draining of mud in the fashion
described above. The previous mud-shut-in test was at average pressure of 34.8 psig
and the average liquid permeability was about 0.02 md, which is less than the first in-
situ permeability of 14.4 psig (Figure 7.10). In-situ tests 1,2 and 3 were conducted at
increasingly higher pressures. Figure 7.10 shows that the average liquid-permeability
tended to decrease as did variation in liquid-permeability (compare especially the sets
of black squares and white squares). At the highest of the three sets of pressure, two
core plugs developed considerably greater permeabilities ("diamonds," Figure 7.10).
These exceptional events are believed to have been the result of break-through of
mud cake. As pressure increases in the in-srtu fluid~(water only) the mud cake can be
compacted, but it cannot be incremented by layering of day. Under certain conditions
- unspecified here - the mud cake is breached. Thus there is a threshold pressure at
which the retardant effects of mud cake will be overcome.
Mud-cake buildup and shut-in plugging have been shown to be affected by
pressure differences across the core. In Figure 7.11 time between drips is plotted
against test-duration time. Each change in pressure (the lower line) resulted in
changes of characteristic time between drips. The greater the time between drips the
less the effective flow rate. If pressure is constant and the effective flow decreases,
then permeability also decreases.
Mud cake was being established with an initial pressure of 45 psig and a
relatively constant "time between drips" resulted (Figure 7.11, initial stage of test).
When the back-pressure valve was adjusted to provide pressure of 91.9 psig, the
effective time between drips decreased to 39 seconds — indicating a higher flow rate.
Next, flow was stopped and the M&P sub-sections were shut in by ball valves. At this
time pressure was generated by compressed nitrogen; pressure was set at 4.9 psig.
7.20
-------
g
3.
2
c-
0.45
0.4
0.35
0.3
0.25
0.2
0.15
0.1
0.05
0
20 40 60 80 100 120
Water Permeability (md)
140
160
INS1 14.4
INS2 35 psig
INS349.8
Figure 7.10 Effects of pressure on permeability, in-situ conditions, core group
12/7/93; 500 md, Bamsdall sandstone.
7.21
-------
700 -
T 300
-700
0 10000 20000 30000 40000 50000 60000 70000 80000
Time (sec)
Figure 7.11 Effects of pressure on mud-cake buildup and mud-shut-in effluent flow-
rates (time between drips), core in M&P 3.1 core holder, core group
12/7/93; 500 md, Bamsdall sandstone.
7.22
-------
By extrapolating segments of the time-between-drips curve that correspond to 4.9-,
14.6- and 34.8-psig pressures, it is apparent that the 4.9-psig time-between-drips
curve would have increased continually and surpassed the time-between-drips for
both the 14.7- and 35-psig pressures. Thus these data are evidence that in stagnant,
mud-filled systems, the lower pressures produce the greater times between drips,
which imply the lower rates of flow. This would be expected and this is what should
occur in a mud-plugged well as pressures move from overbalanced conditions in the
borehole toward equilibrium with formation pressures. Eventually, at equilibrium, flow
would cease. Inspection of Figure 7.11 shows that change in rates of flow is less than
the corresponding changes in pressure; thus, the result is a higher permeability for
the lower pressures.
Pressure is not a unique independent variable, as demonstrated by the
relationship between average mud-cake-buildup permeabilities for all tests, and
associated pressures; the relationship is shown in Figure 7.12. Eight tests conducted
at about the same pressure resulted in significantly different mud-cake-buildup
permeabilities. In consideration of this matter, other independent variables - such as
nitrogen-permeability .swelling clays or other altering materials - must be taken into
account In a potentially changing environment for a given reservoir the pressure will
have an effect on the resulting effective permeability, based on the discussions of
data shown in Figures 7.8 to 7.10. Data shown in Figure 7.12 would be analogous to
eight different reservoirs.
Trends Among Permeabilities Under Different Environments
Permeabilities from each of the nine core-group tests were averaged for the
various environments: nitrogen, water, mud-cake buildup and in-sjju stagnant fluid. A
plot of average mud-cake-buildup permeabilities against average water-permeabilities
is shown in Figure 7.13. In general, the higher water-permeabilities are correlated
with higher permeabilities under mud-cake-buildup conditions; but the absolute rate of
change in mud-cake-buildup permeability is very small in comparison to change in
water permeability. In other words, on a basis of absolute permeability, in rock of
500-md permeability, mud-cake permeability will not be greatly different from
permeability of rock with 1500 md permeability (about 0.1 md cf. about 0.2 md).
Data shown in Appendix K indicate that oilfield conditions exist where mud
used for plugging wells has segregated in the wellbore into a column composed of
denser-than-original mud below and water above; under such conditions, reduction in
effective permeability of aquifers would be desired. Because these current tests take
into account a rather small number of variables, only a general relationship can be
described for the case of a segregated mud column: Reduction of effective
permeability is normally desired; therefore the ratio of in-situ permeability is plotted
against average water-permeability. Figure 7.14 shows steep variation in the ratio of
in-situ permeability/water-permeability for small values of average water-permeability.
7.23
-------
I 0.1
£
g
I
0.01
0 20 40 60
80 100 120 140 160 180 200
Pressure (PSIG)
Figure 7.12 Average mud-cake buildup permeability versus pressure, all tests listed
in Tables H1 to H10, Appendix H.
7.24
-------
I
0.01
500 1000 1500
Average Water Permeability (md)
2000
2500
Figure 7.13 Relationship of test cores for average mud-cake buildup permeability
versus average water-permeability, all tests listed in Tables H1 to H10,
Appendix H.
7.25
-------
n
I
£
S.
0.1
0.01
0.001
0.0001
0.00001
500 1000 1500
Avenge Water Permeability (md)
2000
2500
Figure 7.14 Ratio of in-situ permeability to water-permeability versus water-
permeability, 50-psi tests (Tables H1 to H10, Appendix H).
7.26
-------
At water-permeability greater than about 200 md the variation is reduced markedly.
For drilling mud similar to that used in tests described here, and for water-
permeabilities in the range of the tests, expected permeability across mud cake in a
water-filled borehole can be estimated from Figure 7.14.
For example, assume that an aquifer was cored and several plugs were taken
from the core. If the core-plugs were evacuated by a vacuum pump, allowed to fill with
water, and tested by a water-permeameter, the average permeability would provide an
entry-point into the X-axis of Figure 7.14. The solid line could be used to estimate this
ratio: (in-situ-fluid permeability)/(water-permeability). This ratio, multiplied by the
average water-permeability, would yield an estimate of permeability across mud cake in
a water-filled borehole.
SETTLING-COLUMN CHARACTERISTICS OF MUD
Mud settles at various rates depending on the constituents of the mixture.
Tests also show that mud settles differently, depending on whether the container is
filled from the top or the bottom. Apparently, air entrained in mud while containers are
filled from the top produces a greater rate of settling as air escapes. Mud tends to
settle for long periods of time. Figures 7.15 and 7.16 illustrate rates of settlement of
mud. Column 2 (described in Table K1, Appendix K) is 2 inches in diameter and
about 67 inches tall. Settling has taken place in it for more than 850 days; it is still
settling. Column 2 was filled from the top with mud of approximately 9 Ib per gallon.
Column 3 is described in Table K2 as being 2 inches in diameter and about 45 inches
tall. The curves are converging after a long period of time, which suggests that the
mixtures of mud are similar.
All test data indicate that mud settles quicker when a column is filled from the top
rather than the bottom. Figure 7.16 shows that in a period of 222 days, a column
filled from the top settled 13.3%, as compared to settlement of 5.6% in a column filled
from the bottom; the column filled from the top settled at more than twice the rate of
the column filled from the bottom. The settlement rate is expected to converge, as
indicated in Figure 7.15 (two top-filled columns are compared), but convergence of
top-filled and bottom-filled columns would be much slower, as indicated in Figure
7.16. Data for Figure 7.16 are in Tables K9 and K10.
Settlement of two top-filled columns is compared for four test dates in Tables K1
through KB. Tables K3 and K4 show the greatest percentage of settlement of all tests
- 52.1%. These data describe settlement over a 9.4-month period that began March
8,1994; this is the second-longest test conducted. Tables K5 through K11 concern a
settlement period of seven to eight months; average settlement was 13%. Tables K9
and K10 set out data of the same test period, for top-filled and bottom-filled columns
respectively.
7.27
-------
200 400 600
Settling Time (days)
800
1000
Settling Tube #2
Settling Tube #3
Figure 7.15 Rate of settlement of mud in Column 2 and Column 3. Mud from mud-
cake buildup test 8/20/92. Containers filled from the top.
7.28
-------
0)
B
100 150
Settling Time (days)
200
250
Filled from Top
Filled from Bottom
Figure 7.16 Comparison of settlement of mud in tubes filled from the top with tubes
filled from the bottom. Mud-cake buildup test 5/12/94.
7.29
-------
Six pairs of settlement-test data, involving three test periods and comparison of
bottom-filled and top-filled columns are shown in Tables K9 through K20. For the six-
to seven-month test period, settlement of top-filled columns averaged 22%, whereas
settlement of bottom-filled columns averaged 7%. For the five- to six-month period,
settlement of top-filled columns averaged 13%; settlement of bottom-filled columns
averaged 6%. A column of mud filled from the bottom on June 22,1994 settled least
of all: 0.72%; a column filled from the top on the same date settled 5.8%. The
settlement-ratio, top-filled column to bottom-filled column, was 8.05. All ratios, top-
filled columns to bottom-filled columns, were in the range of 1.8 to 3.8. Data in Table
K18 are an anomaly; the general ratio of settlement, top-filled column: bottom-filled
column indicates that the difference probably is the result of different properties of mud
emplaced on June 22, 1994.
Results of settlement in bottom-filled columns over three test periods are
recorded in Tables K21 through K23. Settlement ranged from 2.3% to 26.72%, but
the test period was for one month or less. Time-lapse is not sufficient to evaluate
these results accurately. The settling-tubes will be monitored for a long time.
Data about the settling rates of drilling mud is important for implications about
the nature of fluid in boreholes with segregated or segregating drilling mud, and about
the variation of the fluids with depth. Clearly, the in-situ fluid in plugged wells has
meaningful implications about the permeabilities of aquifers.
7.30
-------
APPENDIX A
DRAWINGS AND DEVELOPMENT ASSOCIATED WITH THE ARTIFICIAL
RESERVOIR
ROCK DEVELOPMENT, TESTING AND POURING PROCEDURE
DEVELOPMENT OF THE ARTIFICIAL RESERVOIR
General Procedures in Development
The artificial reservoir was designed to simulate general injection-zone
conditions of rock type, porosity and permeability. Sampling of shallow formations of
sandstone in areas near Oklahoma State University indicated that porosity in the
range of 15 percent to 20 percent, and permeability near 200 millidarcies would be
close to the average properties of injection zones.
ii-Jn ordfTto conform to petroleum-industry standards, advice was sought from
Halhburton Services, a company known to have experimented with construction and
treatment of artificial reservoirs. Experimentation with composition and methods of
compaction of the artificial reservoir stemmed from suggestions given by Mr J
Murphey (see Attachment A1 of this appendix). ' '
Principal components of the artificial reservoir are very fine grained clean
quartz sand, coarse grained quartzose sand (commonly used as a propping agent in
fracturing of formations), and a binder of resin (Figures A1, A2)
Experimentation and construction of bench models initially were modeled after the
Standard Proctor Test, used extensively in Civil Engineering to determine the
moisture content at which soil is at maximal density and maximal strength Mixtures of
sand and resin were placed in a Proctor mold and compacted in various measured
amounts with a 5.5-lb. sliding hammer, dropped consistently through a distance of
??Sro;S*maLely 1 ? A~ Cor examP|e- see Figure A3, and discussion of Sample 1, p.
A26, Attachment A2, this appendix.) Sand-and-resin mixtures do not compact in the
manner of soils, first being "fluffy," and then becoming "rubbery." From the outset
porosity and permeability of the artificial reservoir were judged to be stronalv
dependent on the extent and technique of "tamping."
•_• irtJ!le firlt sa.mP|e of reservoir was made according to recommendations of
Halliburton Services. Its appearance and heft indicated strongly that the rock would
have porosity and permeability in amounts smaller than required for the overall
purposes of the experiment. (The correctness of this hypothesis was demonstrated by
tests conducted early in this endeavor by Amoco (Attachment A2, p. A24).) Numerous
A1
-------
Figure A1 Vials of very fine-grained Oklahoma No.1 quartz sand (left), and
coarse-grained, quartzose "12/20 frac sand", the chief components
of the artificial reservoir.
A2
-------
Figure A2 Disc of hardened resin, the cementing agent in the artificial reservoir.
A3
-------
Figure A3 Standard Procter mold (center), hammer (right), and hydraulic-jack
sample remover.
A4
-------
other samples were made, in general keeping the proportions of sand as
recommended by Halliburton, but reducing the amounts of resin to fractions of the
originally recommended volume (Figure A4; Attachment A2).
The artificial rock used in experiments is composed of about 3 parts (by weight)
of fine-grained quartzose sand to one part 12-20-mesh frac sand, cemented by epoxy
resin. As described above, at the outset of this research, Halliburton Services
recommended 150 Ib. of fine-grained quartzose sand, 50 Ib. of frac sand and 19 Ib of
resin for 2.3 cu. ft. of artificial rock. Proportionally smaller batches, called "1 0
Ha Hiburton," produced artificial rock with about 5% to 10% porosity and 10 to 20
millidarcies of permeability - a substance too "tight" for the intended experiments
Therefore, samples were mixed with reduced volumes of resin; amounts of resin
$•£?? were "n Proportions of 0.5, 0.75, 0.8 and so forth, which were named "0.5
Halliburton, 0.75 Halliburton," and so forth. These fractional mixes produced rock with
porosity in the range of about 13% to 20%, and permeability in the range of 0.1 to 7
Because the artificial rock is intended to function in testing as an analog to
actual rock the desirable range of permeability (for equivalent range of porosity) is
between 100 and 1000 millidarcies. Thus, considerable effort was expended to
determine a method of compaction and to produce amounts of compaction that would
reduce permeability but preserve the general range of porosity. First by combining
drill-press parts, platform scales, compacter-foot and molds, a method was developed
for compaction with results expected to be more predictable than those attained
previously by hand-tamping. A 0.5-Halliburton recipe was used as the test case- the
mixture was compacted into molds with axial loads of 1000, 750 and 500 pounds' A
Pn tho iSS^?laKllI?y 8h°S5 a Jeep gradient in permeability with respect to axial force
hLELTSS' beJ^nnn500 V*75° pounds of force- but a much «""«• gradient
2£?Sw?2,SS - ° P^sofforce- Atthe 1000-pound force, permeability was
about 5800 millidarcies - which is too great for the pertinent experiments.
SfSSlr' n'lfSi*118 curve dictated an axial force much greater than the capability of
the modified dnll-press-and-scales device that was being used.
Procedure for Constructing Artificial Reservoir
„ The artificial sandstone reservoir is encased in a cylinder of very coarse-
hShKo^IlP6"11^1? sandst°ne (F'g"re A5). The function of the outer "shell" of
housing '* P °f effluent to ports in the artificial-reservoir
r Jn Preparation for construction of the two-part artificial reservoir, the inside of the
reservoir housing's steel cylinder must be made free of all residue and foreign
material. Rust and other contaminants were removed by a grinding wheel fine
SJS^oomplBMeeLai^ and a,0610"6- Effluent-ports and gathering lines were
cleared with compressed air, to allow proper flow of fluid through the artificial
• 15^?r ;?al1! of the cy|inc|er were coated with epoxy-resistant Partall paste wax to
inhibit bonding between outer parts of the reservoir and the steel cylinder
AS
-------
;
Figure A4 Molds 4 in. and 1in. diameter, and bench-test samples of artificial
reservoir. Samples were poured to test methods of tamping the wet
reservoir mixture, to test porosity and permeability, and to test
parting-compounds. Parting-compounds were to insure that
reservoir would not adhere to artificial reservoir housing
A6
-------
Figure A5 Interior of artificial reservoir housing, during emplacement
of fine-grained central part of reservoir. Coarse-grained
outer "shell" of reservoir is flush with top of steel housing.
A7
-------
The base of the reservoir housing was covered by a non-asbestos fiber gasket
The steel cylinder was positioned onto the base by forklift, then aligned. Bolts were
placed into the flange of the base and upward through the companion flange of the
basal part of the steel cylinder. The bolts were hand-tightened, then wrench-tightened
in opposing order, to insure constant draw-down of the steel cylinder onto the base
Final tightening was by a hydraulic tprque wrench, to step-up to 2700 ft-lb of torque in
500 ft-lb increments; tightening was in opposite-order.
To pour the epoxy-and-sand mixture for the highly permeable outer "shell"
(Figure A5), a cylindrical galvanized sheet-metal form was placed inside the steel
cylinder and spaced equidistantly at 1 in. from the inner wall. A frac sand-and-epoxy
mix, described in Table A1, was poured into the 1-in.^wide cavity. The slurry was
tamped regularly with a dowel rod, to insure nearly uniform packing. The "shell" was
cured for approximately 48 hours. The galvanized^metal form was removed and the
reservoir housing was cleared of debris.
In preparation to pour the central part of the artificial reservoir, a tamping device
(Figure 4.10) was positioned by forklift onto the upper flange, then bolted into
position. The tamping device was leveled, for proper compression of the sand-and-
epoxy mixture, then connected to a hydraulic pump.
The sand-and-epoxy mixture that composed the main part of the artificial
reservoir was mixed in proportions described in Table A2. The reservoir was poured
in several "lifts," and tamped properly. The reservoir was cured for 1 week, under a
protective cover. The upper surface of the reservoir was painted with epoxy several
times, to seal the rock face.
/r- Wl]en curing was complete, a coring device was placed atop the upper flange
(Figure 4.12), leveled and clamped to the flange. A core of the central part of the
artificial reservoir was cut, top to bottom, to align with the casing attached to the
bottom flange. The core was withdrawn from the reservoir housing, and a gasket
emplaced to cover the upper surface of the sandstone reservoir. The gasket was
bonded to the reservoir with dear silicone. A hole was cut in the center of the gasket
to match the position of the core-hole. The top plate of the artificial-reservoir housing
was secured by bolts, in the manner described above.
Core-plugs for Mud Cake-and-Permeabilitv Tests
Samples of artificial rock constructed in molds of 5-in. diameter were intended to
be analogs of samples to be taken from the large (3-ft. wide by 2-ft. thick) artificial
reservoir used in the Simulated Injection tests. Samples to be collected in the course
of the simulated-injection (SIS) test would be cut from the reservoir along directions
more-or-less perpendicular to the direction of the tamping force. Therefore core
plugs cut from the 5-in.-diameter, 6-in.-high samples were cut normal to the direction
of the tamping force. Tests have shown that significant difference exists in
permeability depending on whether the core is taken perpendicular or parallel to
direction of the tamping force. This is not contrary to conditions recorded from natural
rocks, for permeability commonly differs relative to bedding of strata
A8
-------
TABLE A1 . MIXTURE FOR OUTER "SHELL" OF ARTIFICIALRESERVOIR
Dimensions of shell: Internal diameter: 32.5 in. Outside diameter: 34.5 in. Height:
24.2 in. Volume: 2546.9 cu. in.
MATERIAL WEIGHT
Grams Pounds
12-20 Frac Sand 1557
ER-1 3921.4
C-4 794.4
C-1 317.9
Silane 37.85
TABLE A2. MIXTURE FOR SIMULATED-INJECTION-SYSTEM
(SIS) RESERVOIR
Artificial-reservoir components mixed to 0.95 Halliburton specifications. (See
Appendix A for Halliburton's formula.)
MATERIAL AMOUNT
Grams Pounds Cu. Cm.
Okla. 1 Sand 2174344 4794
12/20 Frac Sand 72483.6 159.8
ER-1 20394.6 45.0
Silane 203 4
C-4 4131.3 9.11
C-1 1638.7 3.61
Core-plugs were drilled, cleaned and then evacuated in a vacuum chamber to
0.24 psia, while stored in water. Permeability of the plugs was measured with Ruska
permeameters, using nitrogen and in some instances, water. In the initial sets of
tests, from trial to trial longer spans of time were required for the 10 mm. of test fluid
to flow through each plug. In one instance, the transit time varied from 1 minute and
44.39 seconds to 4 minutes and 12.65 seconds. Of course this increase cannot be
attributed to instrument error or to operator error, owing to the magnitude of variation.
By removing the cores from the permeameter holder, turning the opposite ends up,
and re-running the tests, the initial transit times were essentially the same as before
Increase of transit time was attributed to migration and "stacking" of "rock flour" from
cutting of the cores. A change in procedure was made and a device was made to
clean the cut core from the central part outward to the ends, with air pressure. Other
steps in the procedure involved various cut-off procedures, use of detergent on core
plugs, and use of a shop vacuum while drilling the core plugs and when removing
plugs from the core. Vacuum was used to clean core plugs after they were trimmed to
proper length.
A9
-------
=i« Extrapolation of the permeability and tamping-force data indicated that tamping
olJl 0^2" d P0t PK°-*lde t(?e ra£ge of Permeability and porosity required for the mud-
StS-3, d, Pei™eability tests. Thus, a series of tests was run on resin mixtures and
tamping forces. The maximum foot-pressure that the artificial-reservoir hydraulic
2Z?IiSpl2fl2e IS 14° psL ^esins of ° 6' °'7' °'8- °-9 and 1 -° "Halliburton" mix
were tested. All the cores were done with the relief valve set so a foot pressure of
1^0 psi was achieved.
to 1 OHiii S!31™d ^ permeability decreased as the mix increased from 0.6
miiiiriLrrfii £ T -J^™8*?^ *?$** from 50 ™Nidarcies to more than 5000
IV ' some °!tne 1-0-mix core plugs had zero permeability. One of the
B'^ JePara!fd at he lift (layer) interface, and one of the 1 0-Halliburton
n ? !?tO ^° Parts d""n9 the coring. The separation and shearing
3 -ha2 nof occurred before, and permeabilities in some cases were lower
desired Vlues;A° a test was devised to use the 0.9-Halliburton mix and foot-
S8 fr?*mi°5 psi to 145 psi' then revjew the distribution of
Results of these tests were that gas permeability was in the ranae of
8 °f ° t0 1°°° millidarcies- Howler, J^tfi^u?w!r?
Outermost Part. Artificial Reservoir
te2S5Le«?f additio"al concern was the outer "skin" shown by several samples- at
2 fSSSff i? sin^nd-sand and the mold (coated on the inside with a waxy
? formed a hardl lustrous surface- indicative of a layer oftob much
1^^ 3 meJ*!raneK0f mucn less Permeab^ty than the
As discussed elsewhere in this report, the design of the
id m°ve ?dially throu9h tne disc * ?fS? a9nd°hen to
wuW be eimnate rT^K10 !6St the nyPothesis that resin-skin-effect
couia oe eliminated, and radial and penphera movement of fluid at the wall of th«»
reservoir housing could be insured, a "shell" of cx>are^rained sandston^was added
±a!^ A6) The *MBS!SSS^
SSdEKT* ^ en°mOUS »™»™V (Attachment A2, Sample
qamr£«e£aiLrH lults Of ?he several samples tested by Amoco are shown in Figure A7
Samples 5 and 6 were in the general range of porosity and permeabiWy expected in
t2nHLlrHjeuCtl,?-C'fSrmatlons; ***** sam&e* contained
^
and resin necessarily were mixed in batches in a mortar box first by hand tt^n^v a
Each "ba
A10
-------
r^^^fe^"*"*^"""--•"-_"' :~-;'--'v-''"-^Tj ;v
Figure A6 A model of the artificial reservoir composed of sand with resin binder
Light-colored portion is mostly very fine-grained quartzose sand Outer
portion is coarse-grained sand, with smaller portion of resin. The outer
shell was designed to permit fluid to move freely at the periphery of
the reservoir, toward ports in the wall of the artificial reservoir housing
A11
-------
10000
S» 1000
I 100
10
10
z
15
Porosity (%)
20
-WU
PPSFRVOIR
(DATA: AMOCO, INC.)!
25
30
Figure A7 Plot of porosity compared to permeability, samples of artificial
reservoir. Tests conducted by Amoco Production Co. (See Attachment A2,
Appendix A).
A12
-------
Figure A8 Artificial reservoir housing, showing view into empty central chamber
Plywood disc supported sheet-metal cylinder, which extended to
within 1 in. of outer wall of reservoir housing. Within this 1-in space
coarse-grained sand and resin were poured to form the highly
permeable outer part of the reservoir.
A13
-------
Figure A9 Interior of artificial reservoir housing, during emplacement of central
part of reservoir. A "lift" of compacted fine-grained sand with resin
binder partly fills the reservoir housing.
A14
-------
Figure A10 Completed reservoir, cured and cored, with top gasket bonded
to reservoir.
A15
-------
SEALING OF RESERVOIR AT CONTACTS WITH BLIND FLANGES
Conditions of the experiment require that all fluid that is injected into the
reservoir flow generally in radial paths, to discharge through ports in the side of the
reservoir housing. Fluids are not to travel along the interfaces between the top and
bottom of the reservoir-disc and the blind flanges of the reservoir housing (Figure
A1 1) Numerous tests were conducted to find strong, sealing adhesive material that
could be placed on the top (and bottom) of the artificial reservoir, under gasket
material that would separate reservoir and blind flange. Strength and flexibility are
necessary properties of the bonding material.
ra«i,A*d£efiv®s, ^ed were of three general types: acrylates, epoxies, and silicones.
SSR? ratena^s te?ted were Polycarbonate plastics, mineral-based fiber materials,
and high-density polyethylene sheeting. Each adhesive was tested for bonding-ability
between the artificial reservoir and the gasket materials (Figure A12) Two adhesives
were effective to acceptable levels: Hardman Acrylic-04050, and Permatex RTV clear
siiicone; Hardman Acrylic-04050 is not available in quantities required for this
experiment A second attribute of Permatex RTV siiicone was tested closely: strength
™£™din9 to*the* £^ger 9"4401 mineral-based fiber gasket material. A knife-edge
compression test (Figure A13) showed that compressive force of 15 250 psi was
fSS!2 At0^epf raie ?? ^hes-ive and the 9asket material; in a tensile-strength test,
£SK? * * a iloai 2L1 ' 1 2° DSI was re°.uired to separate the adhesive from the
S5ZL matenal and from the reservoir material. All gasket materials were tested for
^.mp resjsive strength; all withstood compressive loads of more than 15 000 psi
without damage. ' ^
co=,i KRTV4Sle-a^ Sillcone. Adhesive Sealer 66B was used to form bond and
S2 r ^ ? h*e artificial-reservoir material and the Klinger C-4401 mineral-based
iioer gasket material.
ARTIFICIAL-RESERVOIR SYSTEM
Figure A15 shows the relationship of the artificial rock to the reservoir housing
and the wellhead assembly.
A16
-------
Figure A11 Inner (lower) side of top blind flange of the artificial reservoir housing
The elevated smooth surface between the outer ring of holes and the
central hole will be on top of the artificial reservoir. *
A17
-------
Figure A12 Tabs of polycarbonate gasket material attached to sample of
artificial reservoir, for testing the strengths of bonding agents.
A18
-------
Figure A13 Knife-edge compression test of sample of artificial reservoir, on
Versa-Tester Model 1000 compression-testing device. Test
designed to measure splitting-resistance of adhesive (not visible)
that binds two pieces of rock. The adhesive was tested for
effectiveness of bonding artificial reservoir to gaskets between
reservoir and flanges of artificial reservoir housing. Compression
of 15,250 psi was required to separate materials.
A19
-------
Figure A14 Specimens of artificial reservoir bonded to parts of devices used
in testing for tensile strength of material. Adhesive was tested
on a Riehle Test Machine, for effectiveness of bonding artificial
reservoir to gaskets between reservoir and flanges of artificial
reservoir housing.
A20
-------
Artificial Reservoir Media
8" Reinforced
Concrete Pad
Figure A15 Shaded area shows placement of the artificial reservoir rock.
A21
-------
APPENDIX A
ATTACHMENT A1
HALLIBURTON SERVICES
OEVEUOPMEMT OEfT.
AEGMALD M. IASATER. — HQir
a KOCN. AMMM MM
Hay 8. 1989
Or. Marvin Smith
499 Cordell, South
Oklahoma State University
Stillwater. OK 74078
Dear Or. Smith:
As I mentioned on the phone in our conversation, the following
formulation using epoxy resins and fairly large sand should provide the 200
md "synthetic- formation you need. While this is not the formulation we
routinely use. it should be suitable for your application since no high
temperature cure 1s required. This limits usage of product to temperatures
below 120°F. At higher temperatures the epoxy resin will soften. The
final permeability is dependent upon the effort used in tamping the resin
coated sand down in to the mold. The resin coated sand will have the
texture of a stiff mortar before it hardens.
The following formation will mix about 2.3 cu. ft. It can be handled
in a small cement mixer:
1501 Okla. fl Sand
501 12/20 mesh frac sand
19f mixed epoxy resin (mixed separately, then blended into the mixed
sands.)
Epoxy resin mixture (has a pot life of about 1 hour)
14* 13 oz. of epoxy resin (ER-1)
67 cc. of Silane A-1120
Nix the above for about 5 minutes before continuing.
3f no oz. of epoxy hardener (EPSEAL C-4)
If 3 oz. of accelerator (EPSEAL C-l)
Avoid, adding the accelerator until just before adding the resin mix to
the sand. ' Allow 3-5 minutes to completely mix the accelerator into the
other chemicals and then add the mixed resin to the sand.
A22
-------
Or. Marvin Smith
Hay 8, 1989
page 2
Your test chamber sounds like it is about 13 cu. ft. As this is
probably too large an amount for a single batch. I want to stress that you
should taop the coated sand in firaly. rough up the surface so that it will
blend in with the next batch and repeat the Billing procedure.
Clean the mixer at least every hour, using hot soapy water and a polar
organic solvent. Acetone, isopropyl alcohol, uethyl ethyl ketone. nethyl
ch lore fora are examples of Material which may be used. The resin Bust be
renoved from the mixer and all working tools before it hardens.
The following naterials should provide for two tests.
20001 Okla II sand
6001 12/20 frac sand
20 gal (1821) ER-1 epoxy resin
6 gal (401) EPSEAL C-4
2 gal (131) EPSEAL C-l
1 qt. (946 cc liquid) Si lane A-1120)
I hope that these are satisfactory.
Sincerely,
Joe Murphey
Research Chemist
Water & Sand Control • CRO
JN:sc
cc: R. R. Koch
C. H. HcOuff
J. A. Knox
J. M. Wilson
J. 0. Weaver
C. W. Smith
A23
-------
APPENDIX A
ATTACHMENT A2
MOM COMPANY
LMCT COM
CBMg AHALTSTS DATA EECOTO
OATCl
01
stme
Hi:
matt
AM HELL NO. I
Saapl*
•nahi
1
2
3
4
S
<
a^ck
««ti
—
-_
__
—
__
—_
»«ra««bllltr^tllli«*rel««
lUBiwu
M* team M*«.
Vertical
12.
2*«0.
2S70.
20«0.
111.
324.
fecaaltr
t
C.7
20.1
19.4
20. S
12. f
14.1
SacacMioa
% - PV
Oil
Grata
OMMicy
2.2T
2.SJ
2.40
2.43
•••fer to •tt*ct»*4 OSO docuMnt (••293ART0104) wtaich dcaerlbes '
CIM B«ke-tip of •«cn •rtifiet*! eer«.
Mceclpctaa
•
•.
•
•
•
•
A24
-------
AMOCO PRODUCTION COKPAKY
SHALL CORE
LAB KO.; 258S801
CORE ANALYSIS DATA RECORD DATE; 10-18-89
WELL; O.S.U. - Arcifical Core Plugs
FIELD:
STATE:
API WELL NO.:
r
Sample
Muober
Depch
(fc.)
Perae«bilicy
Killidtrcies
Horiz.
Verc.
Poro-
iicy
Z
Cr«in
Densicy
gm/ce
SAC.
Z - PV
Oil
H20
Description
7.8
17.0
2.39
=103.000
34.S
2.57
•Refer co «ccached OSU document (89293ART010O which describes
the aake-up of e«ch arcificicl core.
SRD
89291ARTOOSO
A25
-------
DESCRIPTION OF SAMPLES OF ARTIFICIAL ROCK, DELIVERED TO J. BOWEN, AMOCO,
BY K. SMITH, OKLA. STATE UNIV., 22 AUG. 89, P. 1/3
Sample 1: Dated 26 July 89 and labelled, in blue, "Full HalIIburton Mix
With Standard Three-lift Proccor Compaction.*"
1. Oklahoma No. 1 Sand: 1020.6 go
2. "12 - 20" Frac sand: 340.2 gm
3. Epoxy Resin-1: 100.7 gm**
4. Epseal C-4 (hardener): 20.4 gm
5. Epseal C-l (accelerator): 8.1 gm
6. Silane: 1 cu cm
Si lane was nixed with Epoxy Resin-1 for 5 minutes. To this mixture were
added Epseal C-4 and C-l. The composite fluid was mixed for 5 minutes,
Chen added to sand in small scream that was blended concinuously by hand
mixing.
* The term "Standard Proctor Compaction" refers to the consolidation of
soil in a mold chat is 4 inches in diameter and 4.5 inches high, part of
a process to.test soil for optimal density. In standard procedure the
mold is filled with three "lifts" of soil; each lift is compacted by Che
dropping of a 5.5-pound hammer through 12 inches for 25 repetitions,
distributed "evenly" across the upper surface of the mold.
The aixture of sand and resin was compacted in a Proccor mold, by dropping
Che S.5-pound hammer through approximately 11 inches. (The mixture of
sand and resin was of a "fluffy" consistency, which allowed Che hammer Co
penetrate coo far and which led Co forcing of Che mixture into Che air-
discharge holes in Che Cubular hammer-guide.) Twenty-five blows were dis-
tributed "evenly" across each life of sand-and-resin.
**A11 weights of fluids* as shown, are misleadingly exact. Measurement
could be controlled Co 0.1 gm. However, actual amounts poured together
and ultimately nixed into sand were somewhat less than shown here,
because of retention of fluid on sides and bottoms of containers. If
measurements of amounts retained are wanted, useful approximations of
the average amounts retained on vessels can be furnished.
Sample 2; Dated 28 July 89 and labelled: 3/4H, w/ Standard Proctor (Com-
paction).
1. Oklahoma No. 1 Sand: 1020.6 gm
2. 12-20 Frac Sand: 340.2 gm
3. Epoxy Resin-1: 75.5 gm
4. Epseal C-4: 15.3 gm
5. Epseal C-l: 6.1 gm
6. Silane: 0.8 cu cm
A26
-------
Description, samples, artificial rock co J. Bowen, AMOCO, from M. Smith,
OSU, 22 Aug. 89. p. T7I
Note: Compacted in standard Proctor fashion, with final compaction of 25
blows onto rigid plastic disc atop sand-and-resin mixture.
Sample 3; Dated 31 July 89 and labelled; "1/2H, w/ Full Proctor (Com-
paction)."
1. Oklahoma Ho. 1 Sand: 1020.6 gm
2. "12 -20" frac Sand: 340.2 gm
3. Epoxy Res in-1: 50.4 gm
4. Epseal C-4: 10.2 gm
5. Epseal C-l: 4.0 gm
6. Silane: 0.5 cu cm
Five compacted lifts were required to produce a full mold. Compaction
seemed to be effective for a few blows, after which the material developed
a rather resilient toughness. Topmost lift was compacted evenly across
the surface, but last impact left a "footprint." The final compaction was
done by putting a rigid plastic disc atop the sand-and-resin nix, and ham-
mering the disc 25 evenly spaced blows.
Samle 4; Dated 8-3-89 and labelled; "Modified Proctor. 1/2 (Hallibui
ton) Mix."
1. Oklahoma Mo. 1 Sand:
2. 12-20 Frac Sand:
3. Epoxy Resin-1:
4. Epseal C-4:
5. Epseal C-l:
6. Silane: 0.5 cu cm
1020.6 gm
340.2 gm
50.4 gm
10.2 gm
4.0 gm
Compaction: With Proctor hammer, to "rubbery" consistency.
Sample 5: Dated 16 Aug. 89 and labelled; "80*."
Sample mixed using standard amounts of sand, but content of resin only
about 80 percent of amount shown in listing under Sample 1. Standard
Proctor compaction.
A27
-------
Description, samples, artificial rock, to J. Bo wen, from M. Smith. OSU,
22 Aug. 89. p. 3/3. ' - * - '
Sample 6; Dated 16 August 89 and labelled; "781".
Staple mixed using standard amounts of sand, but content of resin only
0.78 of amount shown in listing under Sample 1. Standard Proctor com-
paction.
Sample 7! 1 inch in diameter and labelled; "ER"
Molded sample with amount of sand proportional to Halliburton specifica-
tions, but 75 percent of Halliburton specifications for resin. Compacted
by hand, moderately. One end of sample had full mixture of resin
floated" onto surface.
Sample 8: 1 inch in diameter and labelled; "12/20."
Molded sample of 12 - 20 frac sand only, with 75 percent of standard Hal-
liburton resin. Compacted by hand, moderately.
SRDrsdg
89293ART010A
A28
-------
APPENDIX B
DRAWINGS AND DEVELOPMENT OF INSTRUMENTATION
DIAPHRAGM HOUSING
K-*. The diaphragm-seal housing shown in Figure B1 serves as an interface
between fresh-water mud in 5 1/2-in. casing and distilled water in the tubing
connected to the pressure and differential-pressure transducers. Accuracy of
aata collected from the pressure and differential-pressure transducers is
dependent on maintaining this interface. The following is a discussion of
problems and solutions associated with sealing the diaphragm-seal housing.
2!i?SSrafl? nas a flange-type configuration with a 180-deg. convolution.
ae
to a sn\£^ • -*«om housing
<* ,3000 Esi is ^ted. « was assumed that when the
in P'3-06' ^ nousin9 assembled, and the flange bolts torqued to
seal at 300° psi "*" result- '
was checked-for flaws or tears; etc. None was detected The
' tnachine "
iho rJl!Si^i5!!jra9r^s2alIlousin9 was ^assembled and hydrostatically tested under
the conditions descnbed above. Again, the seal leaked at approximately 800psL
"]h "f0! ^v** increased by increments of 10 in.-lb. to a
resuted in a Ieak * *• -•• A n°-ieak
' and
Loctite
and was
B1
-------
li! \
2-1/2"
ri i i
I I I
2-1/2"
_L
Parti
2-1/2"
• I • ¥11 D
in i ; • in i
2-1/2"
Part 2
Diaphragm Housing
(Diaphragm Installed)
Figure B1 Detail of the diaphragm housing for interface between mud and water.
B2
-------
The fact was determined later that due to flexing of the 5 1/2-in. casing, the seal
of the diaphragm seal-housing was good only to 2000 psi. No pressures greater than
2000 psi were expected for the first SIS test. Therefore the assembly procedure was
maintained, at least for the first test.
Consideration of a new design of the diaphragm seal housing is suggested for
any future tests.
PRESSURE AND DIFFERENTIAL-PRESSURE TRANSDUCERS
Figures B2 and B3 show configuration of the connections for specific locations in
the test system. Six down-hole locations are related to configurations in Figure B3.
The bottom-most location does not have a transducer. It is the bottom leg of the
differential-pressure transducer in Location 2, Figure B3. Location 2 is at the salt-
water injection point. Table B1 shows pressure ratings of transducers.
DESIGN OF PISTON-TYPE FLOW METER
A piston assembly with inner and outer seals rides on stainless steel tubing
inside of cylinder (Figure B4). A magnet is shown in-the central part of the figure; this
'5 :Pe ®'ement tnat tn® Temposonics transducer senses, to find position in the piston.
A detailed view is shown in Figure B4.
Figure B4 shows the complete assembly of the flow meter. Flow comes in
either end cap and exits at the opposite end cap, depending on the specific direction
of flow. The position of the magnet with respect to time is translated to flow rate
B3
-------
• 138
Location #7
(Artificial Reservoir)
Diaphragm Seal Homing & Transducer
fclocaiide-atowthe '139
AitDda) Resent* Houakig
Mourning tocitlon
honllwO.O.
el toe Artillcltl Retervelr
llaphngrn Seal
Houilno
Oliphrtgm Sttl
Homing
Diaphragm Seal Heuilng
It leaned en Ihe 5 1/3- Cang
6* belew lh« Artlllelal Reeervelr
Figure B2 Configuration of above-ground pressure transducers.
-------
Location «1
Location «2
Hawkig
•33
Locations
#5
Hong
CXaptaagmSol
Howkig
Location
-------
00
CD
• Temposonics
F33^
Piston
Temposonics
Figure B4 Flow-meter assembly, effluent and salt-water systems.
-------
Table B1 Pressure transducer ratings.
PRESSURE
TRANSDUCER
NUMBER
DOWN-HOLE
LOCATION
TRANSDUCER
PRESSURE
136
137
138
139
140
141
142
(SeeFis.B2)
32
33
34
35
36
37
38
(See Fie. B3)
NA
NA
NA
NA
NA
. NA
NA
2
2
3
4
5
6
6
(See Fie. Dl)
ICS
ICS
ICS
Validyne
Validyne
Validyne
Validyne
Validyne
Validyne
Validyne
Validyne
Validyne
Validyne
ICS
1000 PSI
1000PSI
1000 PSI
2PSID
50PSID
250 PSID
1000 PSID
3000 PSID
5 PSID
8 PSID
12.5 PSID
20 PSID
20 PSID
3000 PSI'
B7
-------
APPENDIX C
INSTRUMENT CALIBRATION
PRESSURE TRANSDUCERS AND DIFFERENTIAL-PRESSURE TRANSDUCERS
Conoco, Inc., Ponca City, Oklahoma, donated time and equipment for calibration
of pressure transducers and differential-pressure transducers. A pressure-
measurement system was taken to Conoco's facility and their DH 5501 deadweight-
pressure-tester system was used. This is a highly sensitive and accurate system
Calibration could not have been done without the cooperation of Conoco.
All pre-sized cables, the computer and software, multiplexer, pressure
transducers and differential-pressure transducers were taken to Conoco's laboratory.
Before calibration, these were assembled in configurations of the test system.
Because of time required to balance the system for each pressure, because of
multiple line pressures, and because of sensitivity of the diaphragms, calibratibn was
long and tedious. Conoco supplied an operator and a supervisor, but our personnel
assembled the systems to be calibrated and operated the two computers.
In Figure C1 the DH 5501 system is in the left-tend portion of the photograph
Shown also are instruments, multiplexers, the data-acquisition system and the
computer. The data-reduction computer system is shown in Figure C2.
A closer view of the required system is shown in Figure C3. The long wires are
to connect sensors to the multiplexer, in the down-hole configuration; the long wire
was used to take into account any line-losses. Each transducer was connected to the
appropnate position on the appropriate multiplexer the output was on the digital
voltmeter and the computer screen. All steps taken are required in the actual test-
configuration. Data were stored on floppy disks; the disks were used in the data-
reduction computer.
In order to prevent damage to differential-pressure transducers, a special flow
network was designed and built (Figure C4).
Results of calibration are in Table C1.
C1
-------
Figure C1 General view of facilities for calibration of pressure-transducers
and differential-pressure transducers, at Conoco, Inc., Ponca City
Oklahoma.
C2
-------
Figure C2 Computer system used for calibration of pressure-transducers and
differential-pressure transducers, at Conoco, Inc. Ponca City
Oklahoma.
C3
-------
Figure C3 Instrument lead-lines, transducers (on table-top, at left)
multiplexer ("boxes" with needle-dial output), and digital voltmeter
(lower right-hand comer), devices used to calibrate pressure-
transducers and differential-pressure transducers at Conoco Inc
Ponca City, Oklahoma.
C4
-------
Figure C4 Pressure-equalization network for calibration of differential-
pressure transducers at Conoco, Inc., Ponca City, Oklahoma.
C5
-------
FLOW-METER CALIBRATION
Three flow meters are mounted on the Instrumentation Console (Figure C5)
These three act separately in normal operation but are connected during calibration.
The flow meter for the mud column is connected to the Vindum valve of the salt-water-
injection flow meter; from the output of the salt-water flow meter this is connected to
the input to the reservoir-fluid flow meter. During calibration, the mud-column flow
meter is filled with water and nitrogen pressure is imposed. Thus pressure and fluid
are supplied to drive flow through the salt-water-injection flow meter. Then fluid
moves to the reservoir-effluent flow meter, and from there into a vessel on a scale
(Figure C5). The scale allows readings to a tenth of a gram. The digital data are
recorded on the computer's hard disk (Figure C6).
Each of the three flow meters has a Temposonics linear transducer that
records the position of a magnet. The position of this magnet is measured precisely,
to 0.001 in. By this measurement the amount of flow from the meter can be
determined. The conditioned electrical output of the Temposonics transducer is sent
through a multiplexer to the computer and stored on a hard disk. The multiplexer
"rotates1 the three signals and records them serially.
Also, three pressure transducers are mounted on the flow-meter network
(Figure C7), near the Vindum valves. The 1000-psi pressure transducer mounted on
the downstream side of the salt-water-injection flow meter measures pressure
developed during operation of the flow meter. Pressure transducers are mounted on
either side of the Vindum valves on the reservoir-effluent flow meter. This allows
determination of a pressure differential across the Vindum valves Included in the
console is a 1000-psi pressure gauge on the reservoir-effluent side, and a 1500-psi
pressure gauge is on the salt-water side. All other output to the computer goes to the
multiplexer, so that output is serial; this cycles through at a rate of about 10 per
second.
Before calibration starts, each flow meter must be prepared for operation The
reservoir-effluent flow meter and the salt-water-injection flow meter require that fluid
be on both sides of the pistons, which contain magnets. Doing this requires that air
be bled from the lines. In order to prepare the mud-column flow meter a hose is
connected to the vessel and filled with water. Then nitrogen (Figure C8) is turned on
and pressure is regulated to the level appropriate for calibration. Various ranges of
pressures are measured, so each flow meter is calibrated more than once.
Note that calibration must end temporarily when the mud-column flow-meter
vessel is emptied. Therefore, the amount of flow must be monitored and exposed
during the process. In order to restart the process, nitrogen pressure must be blown
down and the vessel refilled with water and pressurized with nitrogen
C6
-------
Figure C5 Overview of flow-meter calibration system with computer (on cart),
scales, and instrumentation console.
C7
-------
Figure C6 Computer, multiplexer for sensors, power supply, and lead-lines
for calibration of flow meters on instrumentation console.
C8
-------
Figure C7 Front side of instrumentation console. Three flow meters near top
of panel. Pressure transducers (short, cylindrical) are a short
distance below dial.
C9
-------
Figure C8 Back side of instrumentation console, with three flow meters
shown.
C10
-------
The components of these three flow meters are divided into sections on the
console, with some overlap. Basically, the mud-column flow meter is in the right-hand
section of the console. Figures C9 and C10 are focused on these components. On
the left-hand side is the effluent flow meter; some of its components are shown in
Figure C11. Figure C12 is focused upon some of the components associated with the
salt-water-injection flow meter; it is in the central section of the console.
The following abbreviations are used:
V1 = Vindum valve No. 1, which is the top control valve in the reservoir-
effluent flow-meter network.
V2 = Vindum valve No. 2, which is the control valve in the reservoir-effluent
flow-meter network.
V3 = Vindum valve No. 3, which is the top control valve in the salt-water
flow-meter network.
V4 = Vindum valve No. 4, which is the bottom control valve in the salt-water
flow-meter network.
PT = Pressure transducer.
BPV= Back-pressure valve.
CALIBRATION PROCEDURE FOR SIMULTANEOUS FLOW-METER OPERATION
Note: Must have system bled prior to calibrating.
I. Set BPV pressure.
1 Close all ports to V1 and V2 and close BPV (turn clockwise to increase
pressure).
2. Charge the 1 -gal. accumulator with nitrogen to the desired back
pressure.
3. Turn BPV counterclockwise (decrease) until effluent just begins to seep
out of the line.
II. Initialize the flow.
1. Open all ports to Vindum valves V1, V2, V3, and V4.
C11
-------
Figure C9 Electronics, flow-line connections and controls for mud-column
flow meter.
C12
-------
Figure C10 Simulated wellbore-mud column. Flow meter in right-hand side of
photograph.
C13
-------
Figure C11 Electronics, flow lines, controls and line configuration for
calibration of effluent flow meter.
C14
-------
Figure C12 Electronics, flow lines with configuration for calibration of salt-
water flow meter.
C15
-------
2. Increase nitrogen pressure to mud-column flow meter until pressures
equal back pressure.
3. Allow total system to equilibrate.
4. Set Vindum valves V1, V2, V2, and V4 to their operating modes.
5. Slowly increase nitrogen pressure until there is visible flow from
reservoir-effluent line. This initial flow should be as slow as can be
controlled — just a drip or seep.
III. Record data.
1. Set computer to cycle through all activated sensors.
2. Manually record both gauge pressure and the scale output, as well as
date and time. Do this periodically throughout the run.
3. Allow enough time for pistons in flow meters to span their complete
range of travel
4. Allow enough time for the system to equilibrate before going to next flow
rate.
IV. Span the flow range.
1 Increase pressure until flow increases to rate desired.
2. Proceed with Steps 3.1, 3.2, and 3.3.
3. Repeat steps 4.1 and 4.2 until entire flow range has been spanned.
f Span back-pressure range.
1 Do steps I-IV for each back pressure desired.
2. Choose back pressures coincident with test schedule.
C16
-------
APPENDIX D
QUALITY ASSURANCE PLAN
PROJECT OBJECTIVES, DATA USE, AND ACCEPTANCE CRITERIA
PROJECT OBJECTIVES
The principal objective of the proposed research is to determine whether a
predictable relationship exists among standard measured properties of drilling mud,
the in-situ well-plugging fluid, the adjacent reservoir permeability and the differential
pressure (wellbore pressure greater than reservoir pressure) which imply potential
invasion of the reservoir.
Experiments are to be performed at the Oklahoma State University Mud-plug
Facility.
Data Use
Test data would be obtained with the simulated well facility to determine
behavior of the reservoir/wellbore/injection system under different regimes developed
by variance of reservoir, fluid properties and injection pressures. These results
should indicate threshold conditions for the breaching of mud plugs in abandoned
similar wells. In addition, data from this system will be used to determine the settling
characteristics of various muds, as functions of time and pressure under simulated
well conditions.
Mud-cake and effective-permeability tests would provide an array of
information on the relationships among mud properties and in-situ fluid permeabilities
of cores. First, each core would be measured to determine gas permeability, under
standard permeability-testing pressures. Cores would then be tested in a system that
would provide mud cake build-up followed by permeability tests under the same
system. These results should indicate the effect of pressurized wellbore fluids on
permeability of a core shielded by mud cake. Also, gas-permeability test results with
cores from reservoirs, along with mud properties used to drill the well, would yield the
potential for reservoir invasion under various schemes. Altogether, these tests should
serve as a design-tool for guiding mud-plug operations.
For a given drilling mud, tests of settling rates should permit approximation of
the in-place wellbore fluid properties, as a function of depth. This will assist in
D1
-------
analyzing the potential reservoir invasion by wellbore fluids. Figures could be made
to show the variation of mud-density with depth.
Combination of data from simulated-well-facility tests, mud-settling tests, core
gas-permeability tests, and mud-cake and effective-permeability tests should permit
correlation among variables and prediction of potential reservoir encroachment by
wellbore fluids. Data to be treated would include properties of mud used in drilling the
well, gas permeability of the reservoir, reservoir pressure, estimated in-situ wellbore
fluid properties, wellbore pressure, and depth with respect to the mud column. This %
type of correlation could be used for either designing or analyzing mud-plug
operations.
With the data procured, several graphs would be generated to show behavior
of the mud/reservoir/injection system. One figure will show differential pressure
required to cause incipient flow from the wellbore to the reservoir. Mud on and within
walls of a reservoir is analogous to a valve. If differential pressure across a valve
exceeds rated pressure, a valve will leak. Similarly, mud cake in a reservoir will yield
to some differential pressure and allow flow into the reservoir. One result of this study
will be indicated pressure ratings for plugged wells under specified conditions.
Acceptance Criteria
Information obtained during the proposed tests will be regarded as acceptable
If detection of invasion, through the artificial reservoir due to breaching of mud cake,
was successfully monitored and the flow rate measured when invasion occurred.
Additional criteria are that critical variables in the system are to be measured within
prescribed error-bands. These critical variables are flow rate, differential pressure,
mud pressure and temperature, mud properties (constituents, weight, Marsh Funnel
viscosity, plastic viscosity, yield point, apparent viscosity, filtration, pH, gel strength
and resistivity), in-situ wellbore fluid properties and gas permeability of the reservoir
medium. Widths of error-bands should coincide with minimum variations that given
instruments can measure reliably for each variable. These criteria apply to both the
simulated-well-facility system and the mud cake-and-permeameter system.
DATA-QUALITY OBJECTIVES
Successful determination of the differential pressure required to breach a mud
cake and allow flow of fluids into a reservoir is essential to success of the project.
Having a flow meter sufficiently accurate to detect the incipient flow is also of
paramount importance. Depending on the range of pressures measured, an error of
between 0.5 psi and 10 psi for differential pressures across the artificial reservoir will
provide excellent and reliable results. This will be accomplished by using three
differential-pressure transducers with overlapping ranges, to maintain the desired
accuracy. Flow meters would measure flow of liquids injected into the wellbore, mud-
D2
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column movement above the reservoir, and amounts of liquid invading the reservoir
within an error band of 0.001 gallons per hr. for the lower flow rates and up to 0.03
gal. per hr. for the higher flow rates. Flow above 32 gal. per hr. would not be
permitted.
Pressure measurements for the mud cake-and-permeameter tests are to be
made within 0.1 psi, which would provide sufficiently accurate results. Effluent from
these tests would be collected in beakers while being timed. Fluid would be weighed
on a scale that has accuracy of 0.1 gram. Combining the time-and-weight data to
obtain average flow rate would result in an expected error of not more than 0.1 grams
per second.
Temperature would be measured in several test applications, such as down-
hole mud temperature, effluent temperature (from simulated plugged-well tests and
permeameter tests), temperature of mud samples, artificial-reservoir temperature and
mud-column temperature. Error of 1.0 deg. F. (0.56 deg. C.) is the maximum that will
be accepted for this project.
SELECTION OF SAMPLING LOCATIONS AND COLLECTION OF SAMPLES
Pressure, differential pressure and temperature are to be measured down-hole
in the casing Locations of these measurements are shown in Figure D1. Pressure
and differential- pressure-transducer output coupled with the injection location would
provide the most accurate definition of the mud-weight gradient under the test
conditions.
Sampling of effluent from the simulated reservoir will come from locations at 16
positions (two rows of 8) on the periphery of the artificial-reservoir housing. Samples
also will be taken just above and below the two blind flanges on the ends of the 2-ft.-
thick reservoir.
Cores of the artificial reservoir will be collected for laboratory analysis. Upon
disassembly of the reservoir mold and inspection of reservoir material, the reservoir
will be divided into pie sections. Each will be labeled according to radial position,
depth in the reservoir and azimuth. All sections would be assigned a code number
and the reservoir would be sampled by random-number coding. These samples will
be placed in containers, marked, and stored in the analytical laboratory.
Samples of mud will be taken before, during and at the ends of the following
operations:(a) when mud-settling chambers are being filled, (b) when the 5-1/2-in.
casing in the well is being filled, (c) when the mud cake is being formed in the
borehole of the artificial reservoir, and (d) when the mud cake is being formed in the
mud cake-and-permeameter system.
D3
-------
1-1/4" Dia.
Salt Water
Injection Tubing
Injection Pt. - S 4
5-1/2" Casing
10-3/4" Casing
17£
\
171
53'
'
162
.81'
47
81'
47.
36.
40.I
'.62'
22.19'
f
I
T
61> 20'
i.
DO'
*
9" LX*|
i s i
VI L
3
3
--I
1
-i
_JL
8
DPT = Validyne Differential Pressure Transducer
PT = Validyne Pressure Transducer
TC = Temperature Sensor
PT (ICS) = ICS Pressure Transducer
DSH = Diaphragm Seal Housing
Location #6: (*PT, PT (ICS), DSH, TC) __
Location #5: (*PT, DSH, TC)
. Location #4: C*PT, DSH. TC)
. Location #3: (*PT, DSH, TC)
93-
I"
L. Location #2: CPT, PT, DSH, TC)
Location #1: (DSH, TC)
3/4" Steel Plate
Figure D1 Location of tubing and instruments.
D4
-------
Mud will be mixed according to results of evaluating temperature-and-pressure
data from the test well. These specific mixtures will be place in aging-cells, which will
be marked according to depth and date. The aging-cells will be placed in an oven at
the appropriate temperature, to age until injection in the well commences. At that time
shear tests will be run on the samples of mud.
HANDLING, IDENTIFICATION AND STORAGE OF SAMPLES
Core samples from the simulated reservoirs and those made for the
permeability tests will be placed in containers and identified. Each core will be
marked with a date and index number. In addition, the container will be marked with
date and number. A data sheet showing the same date and number will also identify
the location (radius, depth and azimuth) with respect to the simulated reservoir, the
test number, test duration, simulated depth of core and injection point, mud pressure
at the simulated reservoir, injection pressure, and type of injection fluid.
Data will be stored on computer disks and in bound notebooks. Core samples
.will be stored in cabinets in the Mud-test and Storage building.
An interface card that plugs into an IBM PC-AT compatible computer is used to
address a multiplexer input, convert the analog data to digital data, and store the
data.
METHODS OF MEASUREMENT AND PERFORMANCE CHARACTERISTICS
For the most part, methods of measurement are considered to be standard.
Data collection from temperature sensors, pressure sensors, and from flow meters will
be accomplished by a data-acquisition system developed by the Oklahoma State
University Electronics Research and Development Laboratory. This method employs
a down-hole remote-multiplexing scheme for selection of the sensor to be monitored.
a disk, with other applicable information. System software is developed, using
Microsoft Quickbasic 4.5.
An encoder on the interface board is controlled by the computer to select and
hold the sensor addressed, until a value from the sensor is read. The binary address
is encoded into a digital binary signal that is transmitted by shielded twisted-pair wire
to the remote signal conditioner. The signal conditioner identifies the address and
opens the corresponding multiplexer channel of the selected sensor. The output of
the multiplexer containing the selected sensor voltage value is fed back through the
signal conditioner through a shielded twisted-pair wire to the computer interface
board. This precision voltage is fed into a 12-bit analog-to-digital converter. The
digitized value is read by the computer, added to any applicable calibration offset,
converted to an engineering unit (e.g., degrees Fahrenheit), and stored in memory.
At midnight of each day, the data will be stored on disk with day and date, time,
D5
-------
sensor number, and sensor value. Normally, data will be sampled at all sensors at
10-min. intervals.
The test facility, as designed, has the capability to provide an array of
independently controlled variables. These variables are listed below, with explanation
of how they will differ and the ranges of expected values.
Injection Depth
The 5-1/2-in. casing has multiple perforations in the central portion of the
bottom joint. As the casing is set in the well by hanging from the slips in the well
head, the adjustment can be made so that the depth below the simulated reservoir is
from 49 to 2000 ft. Initial tests will begin at the 177-ft. depth with the potential to
increase to the 2000-ft. depth below the reservoir by addition of casing joints to the
string. Future projects at depths of 500,1000,1500 and 2000 ft. below the simulated
reservoir are planned. These depths are to be added to the simulated depth of the
artificial reservoir, to give the simulated injection depth. Casing joints are measured
with a steel tape measure and the dimension is marked on the casing.
Depth of Artificial Reservoir (Invaded Formation)
A column of mud in a 5-1/2-in. casing protruding above the artificial reservoir
will be pressurized with a cylinder and a high-pressure nitrogen bottle, to achieve the
pressure at the artificial reservoir commensurate with the mud in the well. This series
of tests will be run only at the Oklahoma Corporation Commission's designated
plugging mud weight of 9 Ibs./gallon. Therefore, the mud weight is 0.468 psiffi., or at
a depth of 1000 ft. the pressure would be 468 psi. To simulate depth, a pressure
would be applied at the artificial reservoir to be commensurate with the mud column at
that depth. Effective depth of the invaded reservoir will be 1,000 feet. Thus, the
maximal simulated depth for injection will be 1177 feet. The effective depth is
measured with a pressure transducer.
Artificial-reservoir Pressure (Invaded Zone)
Reservoir pressure is controlled independently by using the combination of a
nitrogen accumulator and a precision back-pressure valve (Figure D2). The nitrogen
pressure supplies the initial pressure, and the back-pressure control valve maintains
the pressure as flow from the casing pressure overcomes resistance to flow.
Pressure is measured with a pressure transducer and duplicated with a pressure
gauge. Pressure in a reservoir is normally in the range from 0.433 psi/ft to 0.471
psi/ft of depth. The nominal pressure of 0.45 psi/ft of depth is the reference which
shall be used to define the artificial-reservoir pressure. Thus, for 1000 feet the
pressure will be set at 450 psi.
D6
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Bleed I
Vertical Flow
Meter
High Point
Air Bleed
Mud Mixer
Nitrogen Pressurizing System
Salt Water Injection Circuit
..I.. Actuates* 3/9-Tubing
Figure D2 Functional schematic drawing, basic structure of system for mud-cake build-up in artificial
reservoir and for injection.
-------
Injection Pressure
Another bladder-type accumulator will be used to supply fluid to be injected into
the wellbore full of mud. A high-pressure nitrogen bottle will supply pressure to the
bladder, which will force the injection fluid to the wellbore. A tight-band pressure-
control valve will meter nitrogen into the bladder to maintain correct pressure.
Pressures will range from 10 psi above the well pressure at the injection depth to a
maximum of 0.8 psiffi multiplied by the injection depth (unless significant invasion of
the reservoir took place at a lower pressure). With all other variables remaining
constant, injection pressure will be increased and time will be allowed for a reaction to
occur. If nothing detectable happens, then pressure wi.ll be increased and the
process repeated until the reservoir is invaded or the maximum pressure (based on
0.8 psiSft or 1450 psi at the simulated reservoir) is obtained.
Reservoir Properties
A review of some formations in Oklahoma that could be invaded from wellbores
due to injection elsewhere but in lower strata, revealed a porosity range from about
18% to 24%. Three different reservoirs will be simulated. They will have porosities of
approximately 15%, 20%, and 25%. Their respective permeabilities will be
approximately 100, 500 and 1000 millidarcies. The simulated reservoir porosity and
permeability properties will be measured multiple ways. Initial reservoir loading with
water will provide the first porosity data; the second set of data will be measured from
individual samples taken from the artificial reservoir. The complete artificial reservoir
will be measured for permeability by supplying pressure to water in the casing,
monitoring pressure across the radius, and measuring the effluent flow rate. Cores
from the artificial reservoir will be measured in a commercial gas permeameter and in
the mud cake-and-permeameter (M&P) system. Cores molded specifically for the
mud cake-and-permeameter tests will be measured for permeability with the
commercial gas permeameter and the M&P system.
Fluid Properties
The two types of fluid to be used in the test series are salt water and mud. Salt
water will have an approximate gravity of 8.7 pounds/gallon (ppg). This will be used
for the injection fluid for all the simulated-well-system tests. Muds of five properties
will be used in the total tests. Three of these will be used in the simulated-well-
system tests, but all five will be used in the M&P system tests. All the muds will be 9
ppg but will be of five viscosities, ranging from 36 vis. to 72 vis. Measurements made
will be percentage of constituents, gravity, Marsh Funnel viscosity, plastic viscosity,
yield point, apparent viscosity, filtration, pH and resistivity. Each instrument involved
in these measurements is in our inventory; they are commercial ones designed for the
specific uses.
D8
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Test Sequence
Thirty separate system-tests are scheduled over a three-year period. These
tests will be scheduled in parallel. The column-settling (CS) tests will be started first,
then the simulated-well, simulated-injection-system (SIS) tests will be started next;
while these two are in progress, the mud cake-and-permeability (M&P) system tests
will be conducted in a three-series sequence. Table D1 lists the total sequence of
tests, particular types of mud used, and characteristics of the reservoir cores. Test
numbers designate basic properties of the prime parameters. CS 11 designates that
it is a column-settling test; the mud is type 1, and the core is type 1. SIS 11
designates a simulated injection-system-test with type 1 mud and type 1 reservoir
properties. M&P 111 designates a mud cake-and-permeability system test with type 1
mud, type 1 core material, and type 1 permeameter fluid. Note that the designation of
PP or DP associated with the core type indicates a plug poured from a wet mix or a
plug drilled from the artificial reservoir.
below:
Mud types, core-characteristic types and permeameter-fluid types are given
9 Ib/gal. 36 vis., bentonite & barite
9 Ib/gal. 45 vis., bentonite & barite
bentonite & barite
9 Ib/gal. 63 vis., bentonite & barite
9 Ib/gal. 72 vis., bentonite & barite
15% porosity. 100 millidarcies permeability
20% porosity. 500 millidarcies permeability
25% porosity, 1000 millidarcies
rmeabilitv
Water (same as used to mix mud)
9 Ib/gal. 36 vis., bentonite & barite
9 Ib/gal. 54 vis., bentonite & barite
D9
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TABLE D1.
TESTING SEQUENCE FOR MUD-PLUGGING EVALUATION
I 1-
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
12.
13.
14.
15.
16.
17.
18.
19.
20.
21.
22.
23.
24.
25.
26.
27.
28.
29.
30.
CS11
SIS 11
M&P111. 112. 113
M&P121, 122,123
M&P131, 132,133
CS12
SIS 12
M&P111, 112,113
M&P 21 1.212. 21 3
M&P 221, 222, 223
CS13
SIS 13
M&P 121, 122, 123
M&P 231, 232. 233
M&P 41 1,412. 41 3
CS31
SIS 31
M&P 421, 422. 423
M&P 431. 432. 433
M&P 131, 132,133
CS32
SIS 32
M&P 31 1,312. 313
M&P 331, 332. 333
M&P 321. 322. 323
CS51
SIS 51
M&P 521. 522. 523
M&P 531 ,532, 433
M&P 51 1,512, 513
1
1
1
1
1
1
1
1
2
2
1
1
1
2
4
3
3
4
4
1
3
3
3
3
3
5
5
5
5
5
N/A
1 PP
1 PP
2PP
3PP
N/A
2
1 DP
1 PP
2PP
N/A
3
2 DP
3PP
1 PP
N/A
1
2PP
3PP
3 DP
N/A
2
1 DP
3PP
2 DP
N/A
1
2PP
3PP
1 DP
D10
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Test sequence numbers 1 through 5 constitute a test group; also 6 through 10,
11 through 15, 16 through 20, 21 through 25, and 26 through 30 are test groups.
Thus, there are six test groups. The first two tests in each group are to be run in
parallel; the last three tests in each group are to be in series, but in parallel with the
first two tests.
Standards for Measuring Mud-properties and Reservoir-properties
A list of operating procedures is contained in Appendix F; embedded in these are
various standards. Examples of these are listed below:
STANDARD PROCEDURE FOR LABORATORY
TESTING DRILLING FLUIDS
STANDARD PROCEDURE FOR FIELD TESTING
RECOMMENDED PRACTICE FOR DETERMINING
PERMEABILITY OF POROUS MEDIA
RECOMMENDED PRACTICE FOR CORE-ANALYSIS
PROCEDURE
QUALITY CONTROL AND QUALITY ASSURANCE
Quality control and quality assurance are to be accomplished through
implementation of logical guidelines and operational procedures. A series of steps to
achieve the test-objectives is outlined in this document. These steps are supported
with specific operating procedures that are listed in Appendix D-1. Integrated into
these procedures are sampling methods, ways of storage and preparation of samples,
and methods of analysis. Also included are measurement techniques, quality-control
measures and methods of working with data. Methods of minimizing down-time and
ways to recover data if parts of the system fail are included in specific procedures.
DATA REDUCTION AND REPORTING
Field and laboratory data will be recorded on floppy disks and on forms that
itemize each variable required, the data, and the assigned test-number. A "Comment"
section will be provided for recording of pertinent information. The hand-written
documents will be completed in a periodic manner until an extraordinary event is
detected; then a higher frequency of data-procurement could be desirable. The forms
will be amenable to entry of data into a computer. Most of the data will be recorded
electronically and continuously, with the data-collecting system, and will be stored on
D11
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disks. With all this information, a data-base will be established to provide easy access
for data-reduction programs.
Multivariate linear regression analysis will be used to estimate significant
statistical parameters. Nonlinear regression analysis will be applied to models to
determine empirical correlation equations.
Data will be reported in tabular form and in graphical form, to enhance clarity of
results. Preliminary data will be supplied in quarterly reports; data will be shown in
completeness in the final report.
Characteristics of Computer Data System
Most the data will be processed directly into the computer and saved on the hard
disk; then a "back-up" floppy disk copy will be made. Periodic printouts will be made to
allow review of the data in progress. A range of expected values for variables will be
used to compare with the computer output, to determine the validity of data. Calibration
processing and conversion to engineering units will be achieved through data reduction
using Quattro Pro software. Hardware and software for the data-acquisition system has
been designed and built by personnel of Oklahoma State University who develop
telemetry systems for military and civilian scientific rocket space programs. Each
sensor will be calibrated while on the surface and the calibration curve programmed in
the software. A dead-weight tester will be the standard for pressure calibration. A
precision thermometer and an environmental chamber will provide the means of
calibrating temperature sensors. A calibration check will be made prior to each time
fresh mud is put into the well. This will be done by displacing the old mud, flushing
water through the well and having clean water in the well. By knowing the temperature
and density of water in the well and by knowing the locations of sensors, pressures and
temperatures can be computed and compared to the sensor outputs displayed on the
computer screen or on a printout.
Software will be generated by faculty and staff at Oklahoma State University; it
will be verified by using known inputs and comparing the output with hand-calculated or
known results. Data-reduction software will be a combination of commercial software
and that generated locally. Regression analysis will be accomplished using a
commercial software package. Files to be read by software for the regression analysis
will be generated by our own software.
Evaluation of data is to be focused upon enhancing data procured from three
test systems, to provide a method of using typical information from actual wells, to
predict the pressure in a wellbore sufficient to cause invasion of the reservoir. The
"typical information" referred to includes weight and viscosity of mud used to drill the
well, gas permeability of the reservoir, reservoir pressure, properties of mud used to
D12
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plug the well, location of the cement plug relative to the zone being evaluated, and
height of the mud-plug column.
Data from the CS tests will be reduced to fluid properties versus position within
the settling column. These tests will be for three specific muds. Thus, interpolation of
the data would allow additional muds to be analyzed for settling characteristics.
Gas permeability of cores used in the mud-plug-and-permeability tests will be
one of the parameters to relate to the typical well information. Data from the M & P
tests will be correlated so that gas permeability (k-N2) is the independent variable,
and the ratio of effective mud permeability to viscosity (k/u-Eff) is the dependent
variable, with parametric variables of in-situ wellbore fluid properties and properties of
mud used to build the mud cake.
Data from the SIS tests will be reduced and arranged so that the pressure
applied to the injection point is related to the reservoir differential pressure (dP) for
each mud type. This dP then would become the independent variable for a family of
curves. Parametric values of curves would be radial permeability with respect to water
(k/u-H2O) for the various reservoir material, and the corresponding dependent
variable, which is the radial permeability to viscosity ratio (k/u-SIS) of the SIS Test
System. These curves would define the dP at which incipient flow into the reservoir
occurred. A reference differential pressure (dP-Ref) would be defined as the'dP
(incipient flow) plus an offset dP value to assure that a stable flow condition existed.
These reference dP values would define a unique relationship among pairs of k/u-SIS
and k/p-H20 values.
Next, a relationship between the average values of k-N2 and k/u-K^O values
will be established so that data from the M & P tests and the SIS tests can be
combined. The combined data would be in the format of k/u-Eff being the independent
variable, and k/u-SIS at dP-Ref the dependent variable, with parametric variables of k-
N2 and in-situ wellbore fluid properties.
With these relationships, by knowing k-N2, mud properties and in-situ wellbore
fluid properties from a well, a corresponding value of k/u-Eff can be found . Knowing
k-N2 and K/u-Eff, a corresponding value of k/u-SIS can be found. Using k-N2 a value
of k/p-H2O can be determined . With both k/p-SIS and k/u-H2O known, the value of
dP-Ref can be found, which leads to the differential pressure required to cause
incipient flow into a reservoir. Thus, it is possible to obtain an indication of the
limiting value of injection pressure that could be allowed in a zone of a nearby
plugged well before invasion occurs.
Data from each of the three tests have multiple sets at the same condition, so
that a statistical evaluation can be conducted. Ranges, medians and average
D13
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values will be defined for the sets of data . Regression analysis will be performed to
develop empirical relationships with data relations discussed previously.
Data from the CS and SIS Tests will be evaluated to provide evidence about
qualitative behavior of mud in an abandoned well. Results of these tests will be
applicable only to the family of muds tested.
Uncertainties in Measured Values
Uncertainties or errors in the measured values will vary with each calibration
curve and instrument. A list of the major values measured showing expected errors is
shown in the following table.
TABLE D2
VARIABLES, MAXIMAL READINGS, AND EXPECTED ERRORS,
CS, SIS AND M&P TESTS
1 Pressure difference 1 10psi | 0.05 psi I
Pressure
Temperature
Flow rate - mud
Flow rate - salt water
Flow rate - inj. fluid &
effluent
Flow rate - mud column
3000 psi
30 deg. C
44gpm
5gpm
25gph
115gph
30 psi
0.3 deg. C
1 gpm
0.5 gpm
0.0002 gph
0.0006 gph
D14
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APPENDIX D-1
QUALITY ASSURANCE PLAN
STRUCTURE OF THE GENERAL EXPERIMENT: STEPS WITHIN
ONE CYCLE
STRUCTURE OF SIMULATED INJECTION SYSTEM (SIS) TESTS
Figure D3 indicates the steps that carvbe done in parallel with others and those that
must be done serially.
1. Build artificial reservoir of sand and epoxy. (See Operating Procedure 1,
Appendix F.)
2. Calibrate instruments according to Operating Procedure 2, Appendix F.
3. At pipe rack, mount instruments on casing, according to design of test. (For
example, see Figure D1, which shows design of casing instrumentation for Test
1.) (Also see Operating Procedure 3, Appendix F.)
4. Build casing string with pulling unit and run string into borehole, according to
Operating Procedure 4, Appendix F.
5. First cycle of reservoir-testing only: Fill 5-1/2-in. casing string with water to
clean out, and to double-check calibrations of instruments. (See Operating
Procedure 5, Appendix F.)
6. Measure porosity and permeability of reservoir on Assembly Stand (Figure D4,
Location A) by filling artificial reservoir with salt water and flowing water
through reservoir. (Operating Procedure 6, Appendix F.)
7. Make artificial reservoir ready for placement over borehole, according to
Operating Procedure 7, Appendix F.
8. Homogenize drilling mud. Place mud in 5-iy2-in. casing using tubing set to
bottom of hole. Check instruments by measuring and recording gradient-effects
of mud. (See Operating Procedures 8.1 through 8.4 and 5.3, Appendix F.)
9 Place reservoir over borehole (Figure D4, Location B) and make all
connections for flow-lines, instrumentation and back-pressure controls .
(Operating Procedure 9, Appendix F.)
D15
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o
o>
Test Preparation Phase
-X
V-^ V-X
Pre-test
Phase ~~H
V-X
Test
rPhase '
v^x >^-x v_
Post-test
-i Evaluation
Phase
Data-evaluation
Phase
Figure D3 Sequence of events, one injection test.
-------
Pipe Rack
for 5-1/2"
Casing
and Tubing
Figure D4 OSU/EPA mud test facility.
D17
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10 . At Location B (Figure D4) build mud cake in reservoir section: To retain salt
water in reservoir, make up hammer union . Deflate packer. Displace packer
out top with mud . Circulate mud through wellbore in reservoir. When flow of
mud filtrate radially through reservoir stops, then mud cake is built. Bring
primary mud flow to zero, while maintaining wellbore pressure at simulated
depth, 1000 ft. or 468 psi for 9-lb./gal. mud. (See Operating Procedure 10
Appendix F.)
11. Let mud sit in column until equilibrium is reached, as measured by stabilization
of temperature and pressure gradients across sensors. Monitor for
displacement of fluid from column above reservoir, for detection of leakage in
casing or migration through mud cake. (See Operating Procedure 11, Appendix
12. When mud equilibrates, begin injection of salt water at 10 psi above mud-
column pressure, at injection point. Maintain for period of time judged to be
sufficient for effect at reservoir. If flow from reservoir is undetectable, then
increase injection pressure by increment specified in Operating Procedure
12.3,
Appendix F. However, if flow from reservoir is detectable but less than 0.3 gpm,
then increase pressure by the amount described in Operating Procedure 124
Appendix F. These steps would be repeated until (a) flow rate is equal to or '
greater than 0.3 gpm, or (b) the maximal injection pressure has been achieved.
13. Dismount artificial-reservoir housing and move housing from Location B to
Location A (Figure D4). (Operating Procedure 13, Appendix F.)
14. Collect samples from reservoir according to sampling scheme prescribed for
physical description of reservoir (Operating Procedure 14, Appendix F). Label
and store as prescribed, in preparation for analysis.
15. Evacuate drilling mud in casing by water-displacement. Test calibration of
down-hole sensors. Evacuate water with air, then swab dry (Operating
Procedure 15, Appendix F.)
16. Plot injection pressure against observed flow rates at reservoir-exit. Analyze
these data to describe preservation or loss of reservoir integrity under
experimental conditions. (Operating Procedure 16, Appendix F.)
17. Return to Step 1.
D18
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STRUCTURE OF MUD-COLUMN SETTLING (CS) TESTS
1. Mix mud according to the test schedule. Sample mud and test it. (See
Operating Procedures 8 1 through 8.3, Appendix F.)
2. Transfer mud from mixing tank to settling columns and adjust pressure to
simulated well value. (See Operating Procedure 17.1.2.27, Appendix F.)
3. Allow columns to settle without being disturbed, until settling rate becomes
insignificant. Coordinate with Simulated-well-injection System test. (See
Operating Procedure 11, Appendix F.)
4. Collect samples from settling columns. Take samples at specified column
levels until column is evacuated.
5. Determine properties of mud samples and record data.(See Operating
Procedure 8.3.3, Appendix F.)
6. Transfer excess mud to effluent tank and clean columns and flow lines.
7. Evaluate test results and develop tables and figures which present mud
characteristics with respect to depth of column.
STRUCTURE OF MUD-CAKE AND PERMEABILITY (M&P) SYSTEM TESTS
Figure D5 indicates the steps that can be done in parallel with others and those
that must be done serially
1. Make artificial cores to be evaluated or obtain cores to be tested from the
simulated reservoir. (See Operating Procedure 14, Appendix F.)
2. Prepare cores to be tested in M&P test system.
3. Determine permeability of cores with gas permeameter. (See API RP 40 Sect
3.4.)
4. Measure effective porosity of cores.
D19
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o
M
O
Plugs from
Small Core
Tamper
Plugs from
Artificial
Reservoir
Plugs from
Natural
Sandstone
Test
Jreperation_L Test
Phase
Phase
2nd Tes, P^se
Pre-test
Data
Figure D5 Sequence of events, one M & P test.
-------
5. Mix mud, if not already mixed for the CS and SIS tests. (See Operating
Procedures 8.1 through 8.3, Appendix F.)
6. Measure standard properties of mud to be used in the tests. (See Operating
Procedure 8.3.3, Appendix F.)
7. Place cores in M&P sub-assembly and prepare for tests. (See Operating
Procedure 17, Appendix F.)
8. Determine water permeability using M&P system.
9. Build mud cake on cores while effluent through cores is collected in beakers.
(See Operating Procedure 17, Appendix F.)
10. Isolate sets of cores in M&P system and place desired in-situ well bore fluids in
chambers. (See Operating Procedure 17, Appendix F.)
11. Measure permeabilities of mud-plugged cores with a common pressure source
to all cores in the M&P system. (See Operating Procedure 17, Appendix F.)
12. Obtain samples of mud from chambers of M&P system and measure standard
properties. (See Operating Procedure 17, Appendix F.)
13. Purge system of excess mud; disassemble and clean system. (See Operating
Procedure 17, Appendix F.)
14. Evaluate and record data obtained in each operation in M&P test sequence.
(See Operating Procedure 17, Appendix F.)
D21
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APPENDIX E
NUMBERS AND NAMES OF VALVES, MUD-CAKE AND PERMEABILITY SYSTEM
VALVES LOCATED OUTSIDE EPA OUTDOOR LABORATORY BUILDING
NUMBER NAME
1 Primary-mud-system Drain Valve
2 Primary Return-line Drain Valve
3 Primary Supply-line Drain Valve
4 Primary-mud-system Line Valve
5 Main-line Throttle Valve
6 Main-line Calibration Valve
7 Primary Mud-return Valve
8 Calibration Diversion Valve
9 Main-line Crossover Valve
10 Secondary Mud-tank Return Valve
11 Main-line Supply Valve
12 Main-line Effluent Valve
13 Mud-system Bypass Drain Valve
14 Baird Pressure-regulating Valve
15 Site B Supply-line Valve
16 Mud-pump Bypass Valve (1100 Ibs)
17 Site B Return-line Valve
18 Primary-mud-system Tank Valve: Suction Side (Tank 1)
19 Primary Mud-tank Drain Valve (Tank 1)
20 Site B Main Supply-line Valve
E1
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NUMBER NAME
21 Site B Main Return-line Valve
22 Secondary-mud-system Tank Valve - Suction Side
23 Secondary-mud-system Tank Drain Valve
24 Second Effluent-tank Valve
25 Secondary-mud-system Supply Valve
26 Secondary-mud-system Supply-line Valve
27 Saltwater-injection-system Return-line Valve
28 Saltwater Main-line Calibration Valve
29 Saltwater Calibration Diversion Valve
30 Saltwater-injection Supply-line Valve
31 Site A Main Supply-line valve
32 Salt-water-system Tank Valve (Tank 3)
33 Saltwater-injection-system Drain Valve (Tank 3)
34 First-effluent-tank Drain Valve (Tank 4)
35 Site A Main Return-line Valve
36 Site A Supply Valve
37 Site A Return Valve
VALVES LOCATED INSIDE EPA OUTDOOR LABORATORY BUILDING
NUMBER NAME
38 N itrogen-cylinder Shutoff Valve
39 Main Nitrogen-regulator Valve
40 Supply-line Sample-port Valve
41 Crossover Valve
42 Multicore Permeameter 1 (MCP-1): Inlet-isolation Valve
43 MCP-1 Bleed-port Valve
E2
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NUMBER NAME
44 MCP-1 Core-1 Discharge-tube Valve
45 MCP-1 Core-2 Discharge-tube Valve
46 MCP-1 Injection-port Valve
47 MCP-1 Core-3 Discharge-tube Valve
48 MCP-1 Drain-and-fill Valve
49 MCP-1 Outlet-isolation Valve
50 P-2 Inlet-isolation Valve
51 P Throttle Valve/Back Pressure Valve
52 P-2 Bleed-port Valve
53 P-2 Core-1 Discharge-tube Valve
54 Nitrogen Supply-line Valve
55 MCP-2 Core-2 Discharge-tube Valve
56 MCP-2 Injection-port Valve
57 50-psi Pressure-transducer Isolation Valve
58 MCP-2 Core-3 Discharge-tube Valve
59 MCP-2 Drain-and-fill Valve
60 MCP-2 Outlet-isolation Valve
61 MCP-3 Inlet-isolation Valve
62 MCP-3 Bleed-port Valve
63 MCP-3 Core-1 Discharge-tube Valve
64 MCP-3 Core-2 Discharge-tube Valve
65 MCP-3 Injection-port Valve
66 MCP-3 Core-3 Discharge-tube Valve
67 MCP-3 Drain-and-fill Valve
68 MCP-3 Outlet-isolation Valve
E3
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NUMBER NAME
69 Return-side Sample-port Valve
E4
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APPENDIX F
OPERATING PROCEDURES. SUMMARY LISTING
1. Construction of artificial reservoir.
1.1 Preparation of artificial-reservoir housing to receive sand mixture.
1.2 Preparation of cores, 5 inches in diameter.
1.3 Electrohydraulic control of core-tamping device.
1.4 Preparation of sand mixture.
1.5 Filling of housing with sand mixture.
1.6 Emplacement of top flange, artificial-reservoir housing
2. Primary calibration of instruments.
2.1 Calibration of pressure gauges.
2.2 Calibration of pressure and differential-pressure transducers.
2.3 Calibration of temperature sensors.
2.4 Calibration of flow meters
2.5 Calibration of mud-flow-rate system.
2.6 Calibration of salt-water turbine meter.
3. Mounting of instruments.
3.0 Mounting diaphragm-seal housings.
3.1 Mounting of differential-pressure transducers.
3.2 Mounting of pressure transducers.
3.3 Mounting of temperature transducers.
3.4 Mounting of multiplexers.
3 5 Placing of flow meters.
F1
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3.6 Mounting of pressure gauges.
4. Running instrumented casing string into borehole.
4.0 Pipe selection.
4.1 Positioning casing joint.
4.2 Connecting instrumentation lead-lines.
4.3 Mechanical installation of first joint.
4.4 Mechanical installation of second and all other joints.
4.5 Recording instrumentation position and location on casing string.
4.6 Securing top joint and lead-lines in wellhead.
5. Calibration-check of down-hole sensors and data-acquisition system.
5.1 Emplacement of water in casing string for calibration check of down-hole
sensors.
5.2 Activation and check-out of computerized data-acquisition system.
5.3 Initial calibration-check of sensors.
6. Measurement of overall porosity and permeability.
6.1 Measuring porosity of artificial reservoir within housing.
6.2 Measuring permeability of artificial reservoir within housing.
7. Preparation of artificial reservoir for movement to position above borehole.
7 1 Containment of fluid within artificial reservoir during removal of instruments.
7.2 Installation of reservoir pick-up assembly.
8. Preparation of drilling mud, emplacement in casing and removal from
casing string
8.1 Mixing of mud according to Oklahoma Corporation Commission's standards
for well-plugging.
8.2 Homogenization of drilling mud.
F2
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8.3 Sampling and testing of drilling mud.
8 4 Emplacement of drilling mud in casing string.
8.5 Removal of drilling mud from casing string.
9. Connection of artificial reservoir to casing string.
9.1 Placement of reservoir stand.
9.2 Placement of artificial reservoir on reservoir stand.
10. Building of mud cake.
10.1 Homogenization of drilling mud.
10.2 Displacement of packer.
10.3 Adjustment of flow rate and back-pressure.
10.4 Monitoring of mud-filtrate flow rate.
10.5 Sampling and testing of drilling mud.
10.6 Shut-down procedure and line removal.
10.7 Refined adjustment of pressure to prescribed magnitude.
11. Monitoring for equilibration of mud in casing string.
11.1 Monitoring of mud column for differential pressure, pressure and temperature.
11.2 Monitoring of mud column at simulated-depth conditions for differential
pressure, pressure and temperature.
12. Monitoring effects of salt-water injection.
12.1 Activation of salt-water injection system.
12.2 Monitoring and recording comprehensive pressure differentials pressures
and flow rates.
12.3 Increasing injection pressure in response to undetectable flow from reservoir.
12.4 Increasing injection pressure in response to low rates of flow from reservoir.
12.5 Termination of injection in response to maximized flow or pressure.
F3
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13. Transfer of artificial-reservoir housing from test stand to assembly stand.
13.1 Removal of instrumentation from artificial-reservoir housing.
13.2 Disconnecting reservoir housing from casing string.
13.3 Installation of reservoir pick-up assembly and movement of reservoir housing.
14. Sampling of artificial reservoir.
14.1 Removal of artificial reservoir from housing.
14.2 Mapping and labeling of reservoir surface for random sampling.
14.3 Collection of random samples.
14.4 Labeling and storage of samples.
15. Evacuation of liquids from casing string.
15.1 Displacing drilling mud with water.
15.2 Calibration check of sensors.
15.3 Displacing water with air.
15.4 Shut-down of computerized data-acquisition system.
16. Analysis of data and reporting of conclusions.
16.1 Documentation of software for reduction of data.
16.2 Documentation of software for analysis of data.
16.3 Methods for recording of data.
164 Methods for secure storage of data.
16.5 Methods for reducing data.
16.6 Methods for validating data.
16.7 Definition of data-quality indicators.
16.8 Methods for evaluating quality of data.
16.9 Methods for presenting data.
F4
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16.10 Reporting of conclusions.
17. Multiple-core testing of mud-cake and permeability.
17.1 Multiple-core mud-cake and permeability test procedure.
17.2 Preparation for mud-cake and permeability test.
17.3 Recording numbers of cores.
17.4 Measuring dry-weights of beakers.
17.5 Placement of cores into rubber core-holder sleeves.
17.6 Placement of core and core-holder cap onto M&P Subassembly.
17.7 Placement of beakers under discharge-tubes on M&P Subassemblies.
17.8 Setting valve-positions on M&P Subassemblies.
17.9 Filling M&P Subassembly chamber with water.
17.10 Activate computer: M&P software operation.
17.11 Passage of water through test core.
17.12 Shut-down procedure for software.
17.13 Recording of wet-weight of 100-ml. beakers.
17.14 Shut-down procedure, M&P Subassemblies.
1715 Shutting down computer.
F5
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APPENDIX F
OPERATING PROCEDURE 1.1
PREPARATION OF ARTIFICIAL-RESERVOIR HOUSING
TO RECEIVE SAND MIXTURE
1.1.1 Install gasket between bottom blind flange and bottom flange.
1.1.2 Bolt flange halves together.
1.1.2.1 Insert bolts and screw nuts on, hand-tight.
1.1.2.2 Torque to 2500 ft.-lb. Tighten one nut; move to 180-deg. position-
tighten that nut.
1.1.2.3 Move to next nut in clockwise direction and tighten it.
1.1.2.4 Move to 180-deg. position; tighten that nut.
1.1.2.5 Move to next nut in clockwise manner and tighten it.
1.1.2.6 Repeat this pattern until all nuts are torqued to 500 ft.-lb.
1.1.2.7 Repeat the same pattern at 1000 ft -Ib. and 2000 ft -Ib torque
and finally at 2500 ft.-lb. '
1.1.3 Clean surfaces on inside of artificial-reservoir housing.
1.1.4 Place form in housing to pour high-porosity outer shell.
1.1.4.1 Plug central hole in bottom flange, artificial reservoir housing.
1.1.4.2 Place galvanized sheet-metal liner inside upright steel cylinder
uniformly at 2 in. from inner wall. Tape butt-joint with aluminum tape.
1.1.4.3 Uniformly put parting compound on surface of sheet-metal form
for making outer shell.
1.1.5 Place borehole form in 5-1/2-in. casing.
1.1.5.1 After outer shell has cured for 24 hr., remove form for making shell.
1.1.5.2 Roll a 3 ft.-by-20 in sheet of HOPE so that it fits tightly on inside of
casing. Place in lower casing so that top of rolled sheet is above top
flange by about 1 in. Fill HOPE with sand to retain desired shape Wrap
fine woven screen around HOPE. Place movable screen clamps
F6
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around screen near pour-level. Move clamps up as number of
lifts increases.
OPERATING PROCEDURE 1.2
PREPARATION OF CORES, 5 INCHES IN DIAMETER
1.2.1 Preparation of components.
1.2.1.1 Weigh out amounts of Oklahoma No.1 and 12-20 Frac Sand
needed for mix.
1.2.1.2 Pour Oklahoma No.1 and 12-20 Frac Sand into clean stainless steel
mixing bowl.
1.2.1.3 Mix Oklahoma No.1 and 12-20 Frac Sand with putty knife.
1.2.1.4 Weigh amounts of ER-1, Silane, C-1 and C-4 needed for mix
(See Appendix A, Attachment A1, letter from J. Murphey,
Halliburton Co.).
1.2.1.5 Place empty syringe on "AND" scale and press the "RE-ZERO" button.
1.2.1.6 Fill syringe with desired epoxy component (ER-1, Silane, C-1 or C-4).
1.2.1.7 Place full syringe on "AND" scale and reweigh.
1.2.1.8 If amount of epoxy is greater than needed, eject excess and reweigh.
1.2.1.9 Repeat 1.2.1.8 until desired amount of epoxy is obtained.
1.2.2 Mixing of components.
1.2.2.1 In clean 100-ml beaker, add Silane to ER-1 and stir for 5 minutes.
1.2.2.2 In same 100-ml beaker, add C-1 and C-4; stir for 5 more minutes
(Note: Steps 1.2.2.1 and 1.2.2.2 should take 10 minutes to complete.)
1.2.2.3 Pour resin into sand. Using putty knife, scoop some sand into beaker
Mix sand and excess resin. This will clean the beaker somewhat and
remove most of excess resin.
1.2.2 4 Mix sand and resin until grains are well coated. No dark clumps of
resin should remain. (This should take approximately 10 minutes.)
1.2.3 Preparation for tamping mixture into core-holder.
1.2.3.1 Clean-core molds with abrasive pad.
1.2.3.2 Wipe a thin coat of PART-ALL on the insides of core-molds.
F7
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Wipe off excess.
1.2.3.3 Clean off HOPE disks
1.2.3.4 Plug in Electrohydraulic Tamping Device (ETD).
1.2.3.5 Open cover of ETD.
1.2.3.6 Locate the "RUN, MONITOR, PROGRAM" switch on the PLC
Switch to "PROGRAM" position.
1.2.3.7 Press [CLR] [MONTR] [CLR]; "0000" should be displayed on the
screen.
1.2.3.8 Press [SRCH] twice, or until "0031 PROGR CHK END (01)" is
displayed on screen.
1.2.3.9 Press the up-arrow key. "0030 CNT DATA #0000" should be displayed
("0000" is some number of tamps.)
1.2.3.10 Enter the desired number of tamps.
1.2.3.11 Press [WRITE].
1.2.3.12 Switch the "RUN, MONITOR, PROGRAM" switch back to "RUN".
1.2.4 Test run of tamping.
1.2.4.1 Leave pump switch OFF.
1.2.4.2 Press the "UP" button on the front cover of ETD
(This resets the tamper control.)
1.2.4.3 Press the "START TAMPING" button on front cover of ETD.
(This enters the new number of tamps required.)
1.2.4.4 Close front cover.
1.2.5 Tamping.
1.2.5 1 Assemble core mold. (Place core mold onto core-mold holder.)
1.2.5.2 Place an HOPE disk into bottom of mold.
1.2.5.3 Place sand-resin mixture into core-mold. Level out mixture with
putty knife.
1.2.5.4 Place HDPE disk on top of mixture.
1.2.5.5 Place core-mold under tamping foot of cylinder.
1.2.5.6 Align "ZERO" mark on mold to "ZERO" mark on tamping foot.
F8
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1.2.5.7 Turn on hydraulic pump.
1.2.5.8 Press "DOWN" button on ETD cover, to lower tamping foot into mold
as far as possible.
1.2.5.9 Press "START TAMPING" button on ETD cover to begin the tamping.
1.2.5.10 After tamping is complete, press "UP" button.
1.2.5.11 Remove core mold.
1.2.5.12 If core is to be composed of more than one lift, remove top HOPE disk
and rough up surface of sand-resin mixture, to approximately 1/4 in.
deep.
1.2.5.13 Add next amount of sand-resin mixture and level with putty knife.
1.2.5.14 Replace HOPE disk.
1.2.5.15 Repeat steps 1.2.5.6 through 1.2.5.15, as needed.
1.2.5.16 Remove core-mold; turn off and unplug ETD.
1.2.6 Procedure for coring: removing core from core-mold.
1.2.6.1 Align core-mold under tamping foot of cylinder.
1.2.6.2 Shim under core-mold with 1-in. core sleeves.
1.2.6.3 Plug in and turn on ETD pump.
1.2.6.4 Press "DOWN" button on ETD front cover until core extends the
length of shim.
1.2.6.5 Repeat steps 1.2.6.2 and 1.2.6.4.
1.2.6.6 Before core drops out of mold, mark the "Zero" mark in red ink,
vertically the length of core.
1.2.6.7 Finish removing core
1.2.6.8 Mark top of core with small red "T."
1.2.6.9 Remove core
1.2.6.10 Turn off pump and unplug ETD.
1.2.7 Procedure for coring: labeling of core.
1.2.7.1 Use angle template to mark red lines from 0 to 180 degrees and 90 to
270 degrees. Draw lines on top of core.
F9
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1.2.7.2 Label angles counter-clockwise from zero degrees to 270 degrees.
1.2.7.3 If more than one lift is used, label the lifts A, B, C, etc., from
top to bottom.
1.2.7.4 Label to show the date mixed, halliburton mixture and number of
tamps. Example. 031894.PRM, 0.95 HB, 30% increase, 120T.
1.2.8 Procedure for coring, labeling of core plugs.
1.2.8.1 Label each end of core plugs, to show date mixed, radius, angle lift
and core number. Label in black ink. Radius is 1 for outside diameter
0 for center. Angle is 0, 90,180, or 270 degrees.
Lift is A, B, C...etc. Core numbers range from 1 to 5
Example: 031894. PRM, 1, 0, A, No. 1.
1.2.8.2 Labeling of small core plugs (1.375 in. long by 1 in. in diameter)-
Place, labels on sides of plugs; repeat step 1.2.8.1.
OPERATING PROCEDURE 1.3
ELECTROHYDRAULIC CONTROL OF CORE-TAMPING DEVICE
1.3.1 Programming the number of tamps.
1.3.1.1 Plug in power supply and pump. .
1.3.1.2 Insert keyboard into the PLC.
1.3.1.3 Turn key to "program."
1.3.1.4 Press key until "END" is seen on display.
1.3.1.5 Press key once; a number between 1 and 1000 should
be on display.
1.3.1.6 Press key; enter number of required tamps.
1.3.1.7 Press key. This will enter the number of tamps into program.
1.31.8 Turn key to "RUN" and press side clips to remove keyboard.
1.3.2 Procedure for tamping.
1.3.2.1 Extend cylinder until it stops.
1.3.2.2 Read pressure gauge. If gauge does not record desired pressure
Then turn relief-valve handle "CW" until proper pressure
is recorded.
F10
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1.3.2.3 When proper pressure is recorded, then close FCV valve
(to left of gauge) by turning CW (This operation removes pressure
gauge from system and protects it from damage.)
1.3.2.4 With mold in position, push "Down" button and hold down. (This
operatipnextends cylinder to tamping position; cylinder stops when
button is released.)
1.3.2.5 Sample is ready for tamping. Push and release "Start Tamping"
button. (This operation activates tamping-control circuit. Sample will
be tamped, the number of repetitions entered by operation 1.3.1.7.)
1.3.2.6 After tamping is complete, push "UP" button. Cylinder will retract from
core-mold.
1.3.2.7 Do not push more than one button at a time. Pressing two or more
buttons simultaneously will do serious damage to the computer.
1.3.2.8 Unplug power cords to power supply and to pump.
OPERATING PROCEDURE 1.4
PREPARATION OF SAND MIXTURE
1.4.1 Weight calculations.
1.4.1.1 Use Halliburton guidelines for weight of mixtures for sand and
components of bonding agent. (See Appendix A, Attachment A1,
letter from J. Murphy, Halliburton Co.)
1.4.1.2 Place scales under vented hood for weighing components of bonding
agents. Wear protective clothing. Mix one lift at a time. One lift is
1/6 of total. Amount of bonding agent dependent on permeability
and porosity desired.
1.4.1.3 Weigh sand components; place in 40-gal.containers and have divided
to make six lifts.
1.4.1.4 Mix sand components in mortar-box with Mantis roto-tiller.
1.4.1.5 Mix components of bonding agent in sequence and timing specified
by Halliburton. Mix under fume hood and wear protective clothing.
1 4.1.6 Pour mixed bonding agent evenly over sand in 5-ft mortar-box
and mix with roto-tiller until sand is uniformly in "fluffy" state
(Note that this is an art.)
1.4.1.7 Immediately take to artificial-reservoir housing by forklift and begin
placement.
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OPERATING PROCEDURE 1.5
FILLING OF HOUSING WITH SAND MIXTURE
1.5.1 Outer shell mixture.
1.5.1.1 With forms in place and secured, pour high-porosity sand mixture
evenly around periphery of mold at about 2-in. depth. Tamp
mixture until a "bouncy" reaction takes place,
suggesting a "dough-like" consistency. (Note: this is an art.)
1.5.1.2 Repeat Step 1.5.1.1 until the final compaction is even with top of
reservoir housing.
1.5.2 Primary reservoir mixture.
1.5.2.1 Place sand-and-epoxy mixture in SIS reservoir housing in levelled
lift of approximately 6 inches.
1.5.2.2 Tamp the mixture six times at system pressure of 1761 psig. ( Note:
1761 psig corresponds to 135.0 psi of foot pressure on tamping device.
This pressure is consistent with tamping pressure used to make cores
of artificial sandstone 5 in. in diameter, for use in mud-cake and
permeability testing system)
1.5.2.3 Repeat steps 4 through 7, until mixture is quite near the top of
reservoir housing.
1.5.2.4 Place a one-inch lift in housing; level same.
1.5.2.5 Tamp 6 times at 1761 psig.
1.5.2.6 Repeat one-inch lifts until material is at top of reservoir.
1.5.2.7 Screed excess material to be flush with top of flange
1.5.2.8 Mix epoxy to coat top of reservoir thoroughly.
1.5.2.9 Allow reservoir to cure; add coats of epoxy until reservoir is sealed.
OPERATING PROCEDURE 1.6
EMPLACEMENT OF TOP FLANGE, ARTIFICIAL-RESERVOIR HOUSING
1.6.1 Place gasket over RTV 66 and center on housing.
1.6.2 Using forklift, place top flange carefully on housing, making sure that
alignment allows the borehole form to fit on inside of upper 5-1/2-in
casing. Align bolt holes and place full weight of flange on housing.
1.6.3 Secure flange according to Operating Procedure 1.1.2.
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1.6.4 After mixture has cured, remove bullplug at bottom of 5-1/2-in. casing
and remove sand from mold. Remove the HDPE borehole mold and
then screen
OPERATING PROCEDURE 2 1
CALIBRATION OF PRESSURE GAUGES
2.1.1 Prepare deadweight tester for calibration of instruments.
2.1.1.1 Check level of oil in reservoir of deadweight tester.
2.1.1.2 Insure that weight mechanism spins freely.
2.1.1.3 Assemble weights necessary for desired range of tests.
2.1.2 Calibration of pressure gauges.
2.1.2.1 Mount gauge on deadweight tester.
2.1.2.2 Adjust needle on gauge face to be zero.
2.1.2.3 Assemble set of weights equal to mid-span of gauge and place
on deadweight tester.
2.1.2.4 Adjust span of gauge so that needle on gauge face reads
amount equal to weight load.
2.1.2.5 Remove weight load. Repeat Steps 2.1.2.3 and 2.1.2.4 until registry
at zero and midweight, respectively, are achieved.
2.1.2.6 Assemble set of weights appropriate for span and accuracy of gauge.
2.1.2.7 On gauge-calibration sheet, record sequence of weights.
2.1.2.8 Place weight on deadweight tester. Check weight shaft for free
spin and free float. Record needle reading.
2 1.2.9 Add weight according to sequence specified in Step 2.1.2.7,
and repeat Step 2.1.2.8, until maximal pressure is reached.
2.1.2.10 To determine gauge hysteresis, remove weights one at a time.
With each removal, record needle reading properly on
guage-calibration sheet.
2.1.2.11 If repeatability is outside range of accuracy for gauge under testinq
then repeat Steps 2.1 through 2.1.2.10.
2.1.2.12 If operations have been conducted as prescribed and observations
repeatedly lie outside the range of accuracy, then reject gauge..
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2.1.2.13 For an acceptable transducer, analyze calibration data and define
a calibration equation for the given gauge.
OPERATING PROCEDURE 2.2
CALIBRATION OF PRESSURE AND DIFFERENTIAL-PRESSURE TRANSDUCERS
2.2.1 Preparation for calibration.
2.2.1.1 Measure and cut all instrument lead-lines.
2.2.1.2 Connect instrument connectors to each lead-line.
2.2.1.3 Pre-plumb all pressure and differential-pressure transducers
with appropriate fittings and tubing. Refer to Figures B2 and B3.
2.2.1.4 Number all pressure and differential-pressure transducers
according to location.
2.2.1.5 Gather all material, equipment, and tools for calibration.
2.2.2 Calibration of pressure and differential-pressure transducers.
2.2.2.1 A DESGRANGES et HUOT, deadweight pressure tester
type 5500 is used to calibrate.
2.2.2.2 Deadweight pressure tester for calibration of transducers is located
at Research and Development Complex, Conoco,Inc.,
Ponca City, Oklahoma.
2.2.2.3 All material, equipment, and tools are transported to Ponca City.
2.2.2.4 Calibration of pressure and differential-pressure transducer is
accomplished using procedures outlined in:
DESGRANGES et HUOT PRESSURE STANDARDS
Deadweight Pressure Tester
Type 5500
Technical Manual
OPERATING PROCEDURE 2.3
CALIBRATION OF TEMPERATURE SENSORS
2.3.1 Activate Tenny Environmental Temperature Chamber.
2.3 1.1 Set controls to chill environmental chamber to 0 deg. C.
2.3.1.2 Put Analog Device 590 temperature sensor and the multiplexer
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box into environmental chamber. Connect entire assembly to
electrical power outlet.
2.3.2 Check calibration references.
2.3.2.1 Calibrate Fluke Digital Thermometer and Precision Dial
Thermometer by comparing values at ambient temperature
and by submerging each sensor in ice water (0 deg. C.).
Allow to stabilize for 10 minutes. Readings from these
two points will define calibration of reference sensors.
2.3.2.2 Place both reference sensors into environmental chamber.
Allow to chill and stabilize for 30 min.
2.3.2.3 On Temperature Sensor Calibration form, record temperatures
shown on Fluke and Precision Dial thermometers. Record
millivolt output from all AD 590s.
2.3.2.4 Set controls to elevate environmental chamber to 10 deg. C.
2.3.2.5 Allow chamber and contents to stabilize for 30 minutes.
2.3.2.6 Repeat Step 2.3.2.2.
2.3.2.7 Repeat Steps 2.3.2.3 through 2.3.2.5 at 20 deg. C., 30 deg. C.,
40 deg. C. and 50 deg. C.
2.3.3 Analyze calibration data and define a calibration equation for each sensor.
OPERATING PROCEDURE 2.4
CALIBRATION OF FLOW METERS
The following abbreviations are used:
V1 = Vindum valve No. 1, which is top control valve in reservoir-effluent
flow-meter network.
V2 = Vindum valve No 2, which is control valve in reservoir-effluent
flow-meter network.
V3 = Vindum valve No. 3, which is top control valve in salt-water
flow-meter network.
V4 = Vindum valve No. 4, which is bottom control valve in salt-water
flow-meter network.
PT = Pressure transducer.
BPV = Back-pressure valve.
2.4.1 Make connection changes.
2.4.1.1 Attach hose adapter to inlet of mud-column flow-meter vessel.
2.4.1.2 Connect outlet of mud-column flow meter to V4 inlet with tubing.
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2.4.1.3 Connect outlet of salt-water flow meter to inlet port of
effluent flow meter.
2.4.1.4 Attach line and hose to bleed and draw lines.
2 4.1.5 Connect outlet of effluent flow meter to tubing leading to vessel
on scales.
2.4.2 Bleed the two piston flow meters.
2.4.2.1 Turn valves (vent and supply) to fill mud-column flow meter with
water. When full, shut off vent valve.
2.4.2.2 Circulate water through all flow meters with hydrant pressure.
2.4.2.3 Cycle pistons back and forth until no air comes out of vent lines
from salt-water and effluent flow meters.
2.4.2.4 Shut off water supply and vent valves upon successful bleeding.
2.4.3 Activate computer data-acquisition system.
2.4.3.1 Connect all leads from flow meters, scales and pressure
transducers to the multiplexer.
2.4.3.2 Connect control air to Vindum valves.
2.4.3.3 Activate software on selected instrument cycling.
2.4.4 Set BPV pressure.
2.4.4.1 Close all ports to V1 and V2 and close BPV (turn clockwise
to increase pressure).
2.4.4.2 Charge the 1-gal. accumulator with nitrogen to the desired
back pressure.
2.4.4.3 Turn BPV counterclockwise (decrease) until effluent just begins
to seep out of line.
2.4.5 Initialize flow.
2.4.5.1 Open all ports to the Vindum valves V1, V2, V3 and V4.
2 4.5.2 Increase nitrogen pressure to mud-column flow meter until
pressures equal back pressure.
2.4.5.3 Allow total system to equilibrate.
2.4.5.4 Set Vindum valves V1, V2, V3 and V4 to operating modes.
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2.4.5.5 Slowly increase nitrogen pressure until flow from reservoir-effluent
line is visible. This initial flow should be as slow as can be controlled;
just a drip or a seep.
2.4.6 Record data.
2.4.6.1 Set computer to cycle through all activated sensors.
2.4.6.2 Manually record both gauge pressure and scale.output as well as
date and time. Do this periodically throughout the run.
2.4.6.3 Allow enough time for pistons in flow meters to span complete
ranges of travel.
2.4.6.4 Allow enough time for pistons to equilibrate before going to
next flow rate.
2.4.7 Span the flow range.
2.4.7.1 Increase pressure until flow increases to desired rate.
2.4.7.2 Proceed with Steps 2.4.6.1 through 2.4.6.4.
2.4.7.3 Repeat Steps 2.4.7.1 and 2.4.7.2 until entire flow range has
been spanned.
2.4.8 Span back-pressure range.
2.4.8.1 Do Steps 2.4.4 through 2.4.7 for each back pressure desired.
2.4.8.2 Choose back pressures coincident with test schedule
OPERATING PROCEDURE 2.5
CALIBRATION OF MUD-FLOW-RATE SYSTEM
2.5.1 Circulate pre-mixed mud through recirculating lines for three cycles.
2.5.2 Fourth cycle: Sample mud at 6-min. intervals for 1 hour.
2.5.2 1 At time each sample is collected, measure viscosity by Marsh Funnel
Record measurement on Mud Flow-meter Calibration Sheet.
2.5.2.2 Measure weight/unit volume by precision scales. Record
observations to hundredth of Ib./gal. Record measurement
on Mud Flow-meter Calibration Sheet.
2.5.2.3 Measure pH with pH meter. Record on Mud Flow-meter
Calibration Sheet.
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2.5.3 Calculate means and standard deviations.
2.5.4 Plot means and plus and minus two standard deviations on
Mud-homogenization Quality-control Chart.
2.5.5 If plotted data lie outside rejection limits on Mud-homogenization
Quality-control Chart, then repeat Steps 2.5.2 through 2.5.4.
2.5.6 On Mud Flow-meter Calibration sheet record mean density of mud.
2.5.7 Activate computer and data-acquisition system for flow-rate calibration cycle.
2.5.7.1 Set back-pressure on mud pump at 400 psi.
2.5.7.2 Allow time for circulation system to equilibrate.
2.5.7.3 Set stop watch to zero. Set scales to zero.
2.5.7.4 Divert flexible hose from tank-return port into sample-collection funnel
Simultaneously start stop watch, according to standard
countdown procedure.
2.5.7.5 Fill container to level-indicator.
2.5.7.6 Divert flow back to mud tank; simultaneously trip stop watch,
according to standard countdown procedure.
2.5.7.7 Weigh fluid diverted into sample-container.
2.5.7.8 On Mud Flow-meter Calibration Sheet, record average millivolt
output from tachometer, average pressure-gauge reading
and weight of sample.
2.5.7.9 Empty sample-container and clean same.
2.5.7.10 Repeat Steps 2.5.7.1 through 2.5.7.9 at back-pressures
of 600 psi, 800 psi and 1000 psi.
2.5.7.11 Analyze data and define a calibration-equation for flow rate
as function of back-pressure and revolutions per minute.
OPERATING PROCEDURE 2.6
CALIBRATION OF SALT-WATER TURBINE METER
2.6 1 Connect calibration system to salt-water line.
2.6.2 Connect turbine-meter electrical lead-line to data-acquisition system
and activate computer.
2.6.3 Open valves so that circulation can take place, and begin circulation
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of salt water from tank, and back to tank. Circulate for approximately
30 min. During circulation, check for leaks and other faults.
2.6.4 Adjust back-pressure valve to control flow at approximately 10 gpm, by
using manufacturer's calibration factor.
2.6.5 Allow time for circulation system to equilibrate.
2.6.6 Set stop watch to zero. Set scales to zero.
2.6.7 Divert flexible hose from tank-return port into sample-collection funnel.
Simultaneously start stop watch, according to standard countdown procedure.
2.6.8 Fill container to level-indicator.
2.6.9 Divert flow back to mud tank; simultaneously trip stop watch, according
to standard countdown procedure.
2.6.10 Weigh fluid diverted into sample-container.
2.6.11 On Salt-water Turbine Meter Calibration Sheet record average reading
from turbine meter and weight of sample measured during this time period.
2.6.12 Return salt water from calibration tank to salt-water tank, and clean
calibration tank.
2.6.13 Repeat Steps 2 6.5 through 2.6.12, for 8, 6, 4, 2, 1 and 0.5 gpm.
2.6.14 Analyze data according to Operating Procedure 16.5, and define
calibration-equation for flow rates as function of millivolt output from
turbine meter.
OPERATING PROCEDURE 3.0
MOUNTING DIAPHRAGM-SEAL HOUSINGS
3.0.1 Prepare all components of diaphragm-seal housing assembly for mounting.
3.0.1.1 Inspect diaphragm-housing valves for machining marks and burrs.
3 0.1.2 Check for weld preparation on half to be welded to 5 1/2-in. casing.
3.0 1.3 Clean surfaces to be welded, including removal of paint thread
compound, etc.
3.0.2 Mount bottom diaphragm-seal housing half to 5 1/2-in. casing.
3.0.2.1 Measure and mark position to mount diaphragm-seal housing.
3.0.2.2 Position bottom diaphragm-seal housing on 5 1/2-in. casing.
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3.0.2.3 Weld bottom diaphragm-seal housing half to 5 1/2-in. casing
using MIG welder with CO2 gas shield and 0.035-in. mild steel wire.
3.0.2.4 Check all welds for possible pin holes or leaks.
3.0.2.5 If any visible flaws are apparent, grind out and reweld.
3.0.2.6 Welding should be done in such a way as to keep bending or
warping to a minimum.
3.0.3 Assembly of diaphragm-seal housing.
3.0.3.1 Gather all parts and materials necessary to assemble
diaphragm-seal housings:
- Top half, diaphragm-seal housing
- Diaphragm
- Six 8/32 x 1 1/4-in. grade-8 Allen cap screws
- One 1/4-in. NPT x 1/4-in. CPI fitting
- Allen wrench
- Masking tape
- Locktite safety solvent
- Locktite Fast Cure Epoxy 45
- PST Teflon thread compound
- Paint
3.0.3.2 Gather all tools and equipment needed to assemble
diaphragm-seal housing.
- Air compressor
- Sand blaster
- Sand-blast sand
- Torque wrench in inch-pounds
- End wrench, 9/16-in.
- Drill and drill bits
3.0.3.3 Sand blast both halves, diaphragm-seal housing, to clean white metal.
3.0.3.4 Mask both faces, diaphragm-seal housing with masking tape
and paint inside and outside surfaces. Let paint dry for 24 hrs.
3.0.3.5 Remove masking tape and clean faces with safety solvent.
3.0.3.6 Drill two 1/8-in. holes through 5 1/2-in. casing inside half of
diaphragm-seal housing welded to 5 1/2-in. casing. One should go
toward top and one toward bottom of casing. Refer to Figure B1.
3.0.3.7 Mix Locktite Fast Cure Epoxy 45 according to instructions.
Apply to housing half welded to 5 1/2-in. casing. Initial set-up
time for Epoxy mixture is 5 minutes.
3.0.3.8 Install diaphragm with rubber side to 5 1/2-in. casing. Make sure
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holes in diaphragm are aligned with bolt holes in housing.
3.0.3.9 Apply Epoxy mixture to top-housing half and mate to
bottom-housing half.
3.0.3.10 Apply small amount of PST thread compound on underside of
Allen cap screw head.
3.0.3.11 Insert Al|en cap screw and make up finger-tight with Allen wrench
Epoxy mixture should flow only slightly out all four sides
of housing.
3.0.3.12 Allow Epoxy to cure for a minimum of 24 hr.
3.0.3.13 Torque Allen cap screws to 60 in.-lb.
3.0.3.14 Apply PST thread compound to CPI fitting and make up into
top of housing.
OPERATING PROCEDURE 3.1
MOUNTING OF DIFFERENTIAL-PRESSURE TRANSDUCERS
3.1.1 Prepare differential-pressure transducers for mounting.
3.1.1.1 Differential-pressure transducers have been calibrated previously
Refer to Operating Procedure 2.2.
3.1.1.2 Locations 2, 3, 4, 5 and 6 are to have one differential-pressure
transducer mounted to each; Location 7 has four each
See Figures G2, B2, and B3 for detail of locations.
3.1.1.3 Each differential-pressure transducer is to be filled with distilled
water and bled of all air.
3.1.1.4 Mount differential-pressure transducer to mounting plate and plumb
to system with 1/4-in. stainless steel tubing.
3.1 1.5 All tubing is to be filled with distilled water and bled of air.
OPERATING PROCEDURE 3.2
MOUNTING OF PRESSURE TRANSDUCERS
3.2 1 Prepare pressure transducers for mounting.
3.2.1.1 Pressure transducers have been calibrated previously
Refer to Operating Procedure 2.2.
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3.2.1.2 Locations 2 and 6 (Figure G2) and location 7 (Figure 62) are to have
pressure transducers.
3.2.1.3 Each pressure transducer is to be filled with distilled water and
bled of air.
3.2 1.4 Mount pressure transducer to mounting plate and plumb to
system with 1/4-in. stainless steel tubing
3.2.1.5 All tubing is to be filled with distilled water and bled of air.
OPERATING PROCEDURE 3.3
MOUNTING OF TEMPERATURE TRANSDUCERS
3.3.1 Preparation of temperature sensor for mounting.
3.3.1.1 Temperature sensor has been calibrated previously.
Refer to Operating Procedure 2.3.
3.3.1.2 Temperature sensor is placed in a pre-prepared protective
housing and potted for water resistance. Housing is made from
a phenolic material and potted with hot glue.
3.3.2 Preparation of surface of 5 1/2-in. casing, where temperature sensor is
to be mounted.
3.3.2.1 Surface of pipe must be clean of all grease, dirt, pipe-thread
compound or paint.
3.3.2.2 Use of a wire brush or grinder with wire wheel would be suitable.
3.3.3 Mounting temperature sensor.
3.3.3.1 Apply a small amount of thermal-conductive silicone paste
on temperature sensor.
3.3.3.2 Place temperature sensor and housing on 5 1/2-in. casing
at predetermined location.
3.3.3.3 Attach to 5 1/2-in. casing, using large cable ties.
3.3.3.4 Integrate temperature-sensor lead-lines with other lead-lines up
casing.
OPERATING PROCEDURE 3.4
MOUNTING OF MULTIPLEXERS
3.4.1 Attach dummy multiplexer-box to dummy shielding bracket.
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3.4.2 Align this assembly so that axis of multiplexer and long axis of casing are
superincumbent Long axis of base of multiplexer must be the point of tangent
to circumference of casing.
3.4 3 Clamp assembly in proper place.
3.4.4 Weld shielding bracket to casing
3.4.5 Remove dummy multiplexer; replace with actual multiplexer.
3.4.6 Attach instrumentation lead-lines according to wiring diagram.
OPERATING PROCEDURE 3.5
PLACING OF FLOW METERS
3.5.1 Moving flow meters to location.
3.5.1.1 Flow meters will be utilized at Reservoir Assembly Stand (Figure 2
Location A) and at the well stand (Figure 2, Location B). Therefore,
flow meters, associated instrumentation and equipment are mounted
on a model platform.
3.5.2 Connecting flow meters to artificial reservoir.
3.5.2.1 Connect flow meters to artificial reservoir.
3.5.2.2 For Location A refer to Operating Procedure 6.1 and 6.2.
3.5.3 Connect instrumentation as required.
OPERATING PROCEDURE.3.6
MOUNTING OF PRESSURE GAUGES
3.6.1 Preparation of pressure gauges.
3.6.1.1 Pressure gauges have been calibrated previously according to
Operating Procedure 2.1.
3.6.1.2 Pressure gauges are to be mounted at Location 7 (Figure B2) One
should be at top of artificial reservoir and one positioned for radial
effluent of artificial reservoir.
3.6.2 Mounting pressure gauges.
3.6.2.1 Pressure gauges are to be plumbed into system with 1/4-in
stainless steel tubing. See Figure B3.
3.6.2.2 PST thread compound is to be used on all threads and tubing
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connections.
3.6.2.3 Tubing is to be filled with distilled water and bled of all air.
OPERATING PROCEDURE 4.0
PIPE SELECTION
4.0.1 Pipe tally and inspection.
4.0.1.1 All 5 1/2-in. and 1 1/4-in. pipe tallied. Each joint numbered
measured, and length recorded.
4.0.1.2 Each joint inspected for damage to pipe or threads.
4.0.2 Selecting pipe for first test.
4.0.2.1 Four joints of 5 1/2-in. pipe chosen.
1- 44.72ft.
2- 36.63ft.
3- 47.57ft.
4- 47.62ft.
Total -176.54ft.
4.0.2.2 A 6.25-ft-long, 5-1/2-in. diameter casing sub was used to position
string at precise depth and also to position top of casing at a
precise elevation, to receive the artificial reservoir.
4.0.2.3 Five joints of 1 1/4-in. tubing were selected for salt-water injection
string and are shown schematically in Figure G2. The 1 1/4-in
tubing is run alongside the 5 1/2-in. casing.
4.0.2.4 A transition fitting was designed and constructed to change from
1 1/4-in. tubing to 1/2-in. stainless steel tubing with 1/4-in
bleed line (See Figure G1). This was done to accommodate filling of
the 1 1/4-in. tubing string with salt water to allow bleeding the system
of air, and also to allow better passage
through casing head
OPERATING PROCEDURE 4.1
POSITIONING CASING JOINT
4.1.1 Moving pipe from rack to V-door.
4.1.1.1 Pipe is rolled from rack to V-dpor. Care should be taken,
because diaphragm-seal housings and transducer mounting
plates have been welded to casing.
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4.1.1.2 A rope with hook connected to bottom end of casing is used to
pull casing toward well head. Draw works of pulling unit are utilized.
OPERATING PROCEDURE 4.2
CONNECTING INSTRUMENTATION LEAD-LINES
4.2.1 Instrumentation lead-lines
4.2.1.1 All instrumentation lead-line lengths are calculated and cut.
4.2.1.2 Each lead-line instrument end is fitted with appropriate receptacle
or plug, depending on the instrument.
4.2.1.3 Each fitting is potted with a waterproof material (hot glue) to
provide water-tight fittings.
4.2.2 Instrumentation lead-line connections.
4.2.2.1 All instrument lead-line connections are of the form of plug
twist-lock or plug with rubber seal.
4.2.2.2 Cable ties are used to secure lead-lines in place.
OPERATING PROCEDURE 4.3
MECHANICAL INSTALLATION OF FIRST JOINT
(Note: All location numbers refer to Figure G2.)
4.3.1 Preparation of first joint of casing.
4.3.1.1 Measurement rechecked and recorded as 44.72 ft.
4.3.1.2 Locations 1, 2, and 3 measured, marked and recorded respectively
as 39, 31, and 18 ft. from top of joint.
4.3.1.3 Bottom of the joint (40 ft.) located.
4.3.1.4 Joint cut off at 40.5 ft.
4.3.1.5 3/4-in. plate steel cut to fit inside of 5 1/2-in casing (bottom plug).
4.3.1.6 3/4-in. plate steel welded in place, top of plate to top of collar (40 ft.).
4.3.1.6 1 2-in. x 3/4-in plate steel cut for cross brace for 3/4-in.
plate-steel bottom plug.
4.3.1.6.2 2-in. x 3/4-in plate-steel braces welded into place.
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4.3.1.7 Remaining 4.22-ft. section repositioned in line with 5 1/2-in.
casing and welded.
4.3.1.8 Retaining lugs positioned and welded to bottom 4.72 ft. of casing
to hold centralizer (center of centralizer 2 ft. from actual bottom). '
4.3.1.9 Injection point measured 9 ft. from bottom plug and marked
A 90-deg. elbow NPT Schedule 160 machined on one opening to fit
flush with arc of 5 1/2-in casing and weld-prepped on a bevel.
4.3.1.10 90-deg. elbow welded to 5 1/2-in. casing with 9-ft. mark at
center of opening.
4.3.1.11 Change-over nipple collar made up with 90-deg elbow
(change-over from 11/12-in. thread to API 8rd thread).
4.3.1.12 Pressure-transducer mounting plates, consisting of 6-in. x 2-in x
1/4-m. steel plates, are positioned to 5 1/2-in. casing so as to position
center of differential-pressure transducers parallel with center of
diaphragm-seal housing
4.3.1.13 Plate is welded top and bottom.
4.3.1.14 Two mounting plates positioned at Location 2, one on either side
of diaphragm-seal housing.
4.3.1.15 One plate mounted at Locations 3, 4, 5 and 6.
4.3.2 Plumbing the pressure-measurement system.
4.3.2.1 Plumb a 1/4-in. tubing from Location-1 diaphragm-seal housing
to positive side of differential-pressure transducers at
Location 2.
4.3.2.2 Bleed port provided on both positive and negative sides of
all differential-pressure transducers.
4.3.2.3 Bleed ports provided for pressure transducers.
4.3.2.4 A fill valve is placed just above diaphragm-seal housing at
Locations 1, 2, 3, 4 and 5 and at all tubing unions.
4.3.2.5 1/4-in. tubing from negative side of differential-pressure transducer
at Location 2 to top side of diaphragm-seal housing at Location 2.
4.3.2.6 1/4-in. tubing from Location 2 diaphragm-seal housing to
absolute-pressure transducer with bleed port.
4.3.2.7 1/4-in tubing from Location 2 diaphragm-seal housing to positive
side of differential-pressure transducer at Location 3.
4.3.2.8 1/4-in. tubing from negative side of differential-pressure transducer
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at Location 3 to top side of Location 3 seal housing.
4.3.2.9 1/4-in. tubing from Location 3 diaphragm-seal housing fill valve to
top of first joint of casing and extended to point where Location 4
would be.
4.3.3 Hydrostatic-pressure testing of first joint.
4.3.3.1 Plugs for both the 5 1/2-in. casing and 1 1/4-in tubing made
and installed. Plug for 5 1/2-in. casing has a bleed port; plug for
1 1/4-in tubing has a fill port and a bleed port.
4.3.3.2 Pressure transducers and differential-pressure transducers removed
to bleed individually by hand.
4.3.3.3 Absolute-pressure transducer bled in the following manner-
It is held down-side up and, with a syringe and needle, filled with
distilled water.
4.3.3.4 Needle inserted into tubing close to bottom of absolute-pressure
transducer and water injected, forcing all air up and out of pressure
transducer toward top of tubing.
4.3.3.5 Transducer is tapped gently to loosen all entrained air and more
water is injected, assuring that all air is bled from system.
4.3.3.6 Absolute-pressure transducer is placed back onto its mounting
plate and plumbed back into system.
4.3.3.7 Differential-pressure transducer has a diaphragm; therefore both
sides must be bled.
4.3.3.8 Differential-pressure transducer is turned on its side with diaphragm
slightly higher than electronics end. A water-filled syringe-needle
is inserted into tubing and water injected into pressure transducer
until water comes out bleed port. Transducer is tapped gently to
make sure all air is removed.
4 3.3.9 Bleed port is tightened to maintain the bled system while filling the
opposite side.
4.3.3.10 Transducer is turned over and opposite side is treated in
same manner.
4.3.3.11 When both sides are filled, differential-pressure transducer is
mounted on mounting plate and plumbed back into system.
4.3.3.12 5-1/2-in. casing picked up in vertical position, with all bleed ports
open; starting with Location 1 fill valve, water injected with
syringe into tubing. Tubing tapped gently as water injected
insuring that air is not entrained with water. Water injected 'until it
discharges from bleed port at Location 2.
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4.3.3.13 Casing lowered until Location 2 is waist high.
4.3.3.14 Bleed port tightened on Location 2.
4.3.3.15 Water injected into fill valve at Location 2, using same procedure
as 4.3.3.12.
4.3.3.16 Fill valve at Location 2 closed and casing lowered until Location 3
is waist high.
4.3.3.17 Bleed port tightened at Location 2.
4.3.3.18 Water injected at fill port and Location 3, using procedure 4.3.3.12.
4.3.3.19 Casing lowered; plug put on top of tubing and tightened to
close system.
4.3.3.20 Regular tap water used to fill pipe and 1 1/4-in. tubing.
4.3.3.21 Air bled from system and hydrostatic-pressure pump connected.
4.3.3.22 System pressured to 3000 psi.
4.3.3.23 All welds, connections, flanges, pipe and tubing checked for leaks
Provided if leaks are found, system should be drained and leaks
repaired. System refilled and hydrostatic-pressure-tested
Repeat as necessary until no leaks are detected.
4.3.3.24 Drain 5 1/2-in. casing and 1 1/4-in. tubing in preparation to
lower pipe into wellbore.
4.3.4 Installation of instrumented first joint.
4.3.4.1 Connect all instrumentation lead-lines as dictated in
Operating Procedure 4.2.
4.3.4.2 Mount temperature sensor to casing. Refer to Operatina
Procedure 3.3.
4.3.4.3 Secure 1 1/4-in. tubing and all instrument lead-lines using metal
strapping and cable ties as needed. '
4.3.4 4 Raise instrumented casing to vertical position above well base.
4.3 4.5 Attach centralizer to bottom of 5 1/2-in. casing.
4.3 4.6 Lower instrumented casing slowly into well, watching to insure that
instruments remain clear of casing-walls.
4.3.4.7 After instrumented joint is lowered into well, set slips to hold casing
and begin preparations to run remaining casing.
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OPERATING PROCEDURE 4.4
MECHANICAL INSTALLATION OF SECOND AND ALL OTHER JOINTS
4.4.1 Casing preparation.
4.4 1.1 Inspect casing and tubing for damage
4.4 1.2 Place and weld diaphragm housings where needed.
Refer to Operating Procedure 3.0
4.4.2 Installation.
4.4.2.1 Raise casing to vertical position above wellbore.
4.4.2.2 Remove thread protector and apply thread compound to
casing threads.
4.4.2.3 Lower casing to mate with casing in wellbore.
4.4.2.4 Make up casing joint to recommended torque of 2290 ft.-lbs.
4.4.2.5 Raise casing string to position to add 1-1/4-in. tubing.
4 4.2.6 Raise 1 1/4-in. tubing and mate with tubing in well. Make up to
recommended torque of 570 ft.-lbs.
4.4.2.7 Add 1/4-in. tubing for instrumentation as needed.
4 4.2.8 Lower casing into well; stop at 3- to 5-ft. intervals. Place band to
hold 1 1/4-in. tubing, instrumentation lead-lines, and
instrumentation in place at each interval.
4.4.2.9 Lower casing string to appropriate location. Fill and bleed transducers
Refer to Operating Procedures 4.3.3.12 through 4.3.3.18.
4.4.2.10 Mount temperature sensor. Refer to Operating Procedure 3.3.
4.4.2.11 Connect instrument lead-lines. Refer to Operating Procedure 4.2.
4 4.2.12 Secure instrument tubing and lead-lines. See Operating
Procedure 4.4.2.7.
4 4.2.13 Repeat Operating Procedures 4.4.2.6 through 44210 next
casing joint.
4.4.2.14 Repeat Operating Procedures 4.4.2.1 through 4 4.2 12 until all
casing is in wellbore.
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OPERATING PROCEDURE 4.5
RECORDING INSTRUMENTATION POSITION AND LOCATION
ON CASING STRING
4.5 1 Recording locations of instruments.
4.5.1.1 All locations of temperature sensors, pressure gauges, pressure
transducers and differential-pressure transducers are to be measured
and recorded.
4.5.1.2 Each joint of casing is measured and recorded.
4.5.1.3 Each down-hole instrumentation position is measured and recorded
with respect to each casing joint.
4.5.1.4 All above-ground instrumentation positions are
measured and recorded with respect to elevation.
4.5.1.5 Top of casing well-head is base line for all measurements.
OPERATING PROCEDURE 4.6
SECURING TOP JOINT AND LEAD-LINES IN WELLHEAD
4.6.1 Securing lead-lines.
4.6.1.1 A cable hanger is attached to instrumentation lead-lines
approximately 3 ft. below casing wellhead and secured
to 5 1/2-in. casing.
4.6.2 Securing top casing joint in wellhead.
4.6.2.1 Casing is secured in wellhead by slips.
4.6.2.2 A segment (1/12th) of the slips is removed to allow passage of
salt-water-injection tubing and instrumentation lead-lines.
4.6.2.3 A seal bushing, retaining ring and lock ring are installed to secure
slips and casing at desired location.
OPERATING PROCEDURE 5.1
EMPLACEMENT OF WATER IN CASING STRING FOR CALIBRATION CHECK
OF DOWN-HOLE SENSORS
5.1.1 Place 2 3/8-in. tubing in casing string.
51.1.1 Attach 5 1/2-in. x 2 3/8-in. tubing head to casing string with 5 1/2-in
sub and hammer union.
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5.1.1.2 Using pulling unit, run 2 3/8-m. tubing to bottom of casing string.
Lift off bottom no more than 10 in.
5.1.1.3 Set tubing to desired depth.
5.1.2 Fill casing string with water.
5.1.2.1 Plumb water supply to tubing.
5.1.2.2 Plumb discharge piping to 5 1/2-in. tubing head.
5.1.2.3 Fill casing string with water.
5.1.2.4 Leave tubing in casing for placement of mud. Refer to
Operating Procedure 8.4.
OPERATING PROCEDURE 5.2
ACTIVATION AND CHECK-OUT OF COMPUTERIZED
DATA-ACQUISITION SYSTEM.
5.2.1 Connection of instrumentation lead-lines.
5.2.1.1 Make all connections of down-hole sensors to multiplexer.
5.2.1.2 Connect multiplexer to computer.
5.2.2 Activation of data-acquisition system.
5.2.2.1 Power-up computer and all related equipment.
5.2.2.2 Install software and activate control program.
5.2.2.3 Collect enough data to check out-put of all down-hole sensors.
OPERATING PROCEDURE 5.3
INITIAL CALIBRATION-CHECK OF SENSORS
5.3.1 Calculated values.
5.3.1 1 Calculate down-hole pressure at appropriate location.
5.3.1.2 Calculate down-hole temperatures.
5.3.1.3 Adjust for atmospheric and climatic conditions.
5.3.2 Comparison of calculated values with sensor readings.
5.3.2.1 Compare calculated pressures with pressure-transducer readings.
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5.3.2.2 Compare calculated temperatures with temperature-sensor readings.
5.3.2.3 Compare differential-pressure-transducer readings with
zero-calibration point.
5.3.2 4 Record all findings.
OPERATING PROCEDURE 6.1
MEASURING POROSITY OF ARTIFICIAL RESERVOIR WITHIN HOUSING
6.1.1 Determine bulk volume.
6.1.1.1 Artificial reservoir is assembled on Reservoir Assembly Stand
Assembly would include bottom flange and 5 1/2-in casing
sub with appropriate valves and bull plug, reservoir housing with
radial flow lines and plug, top blind flange with 5 1/2-in. casing
sub and 5 1/2-in. hammer-union half, and gaskets for
artificial-reservoir housing.
6.1.1.2 Artificial reservoir is filled with water from a 4000-ml graduated
cylinder, to a point horizontal with top 5 1/2-in casing sub
just inside 5 1/2-in. hammer-union half.
6.1.1.3 Volume of water to fill reservoir to predetermined point is recorded
for porosity calculation and is referred to as "bulk volume."
6.1.2 Determination of pore volume.
6.1.2.1 Place reservoir media in artificial-reservoir housing Refer to
Operating Procedure 1 (Construction of artificial reservoir).
6.1.2.2 Void space is filled with water through reservoir radial-flow lines
and salt-water-injection flow-meter assembly.
6.1.2.3 Record volume of water to fill reservoir to predetermined point
with reservoir media in place.
6.1.2.4 Determine volume of reservoir media placed in reservoir housing.
6.1.2.5 Determine porosity of the coarse, outer reservoir rock
(From Amoco Report Appendix A, Attachment A2.)
6.1.2.6 Calculate pore volume from predetermined values.
6.1.2.7 Determine reservoir-media porosity using volume of reservoir
media and calculated value of pore volume of reservoir media.
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OPERATING PROCEDURE 6.2
MEASURING PERMEABILITY OF ARTIFICIALRESERVOIR WITHIN HOUSING
6.2.1 Place and connect instrumentation console.
6.2.1.1 Fill reservoir with water. Refer to Operating Procedure 6.1.
6.2.1.2 Place instrumentation console next to artificial reservoir at
assembly stand.
6.2.1.3 Connect a line from a water supply to salt-water-injection flow meter.
6.2.1.4 Connect a line from salt-water-injection flow meter to 1/2-in. fitting
welded to bottom bottom 5 1/2-in. casing sub.
6.2.1.5 Connect a line from reservoir radial flow line to effluent flow meter
and back-pressure valve.
6.2.1.6 Connect line from back-pressure control valve to effluent tank
Fill and bleed alt lines.
6.2.2 Determine permeability of reservoir media.
6.2.2.1 With all valves closed, set back-pressure control valve to
predetermined pressure.
6.2.2.2 Set salt-water injection pressure to test pressure above that of
back-pressure.
6.2.2.3 Open valve to wellbore.
6.2.2.4 Open valve to effluent flow meter.
6.2.2.5 Let flow stabilize. Salt-water injection and effluent flow rate
should be equal.
6.2.2.6 Record stabilized flow rate.
6.2.2.7 Record pressures of injection and effluent.
6.2.2.8 Determine all other parameters, such as porosity, viscosity of fluid, etc.
6.2.2.9 Calculate permeability.
OPERATING PROCEDURE 7.1
CONTAINMENT OF FLUID WITHIN ARTIFICIAL RESERVOIR DURING REMOVAL
OF INSTRUMENTS
7.1.1 Containment of fluid
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7.1.1.1 After permeability test all valves are closed.
7.1.1.2 Relieve pressure from system, both the instrumentation console
and artificial reservoir.
7.1.1.3 Disconnect all lines to and from instrumentation console.
7.1.1.4 Move or place instrumentation console away from Reservoir
Assembly Stand.
. 7.1.1.5 Remove tee assembly from top of reservoir.
7.1.1.6 Insert bladder to a position between drilling-mud supply port and
water-injection port on bottom 5 1/2-in. casing sub.
7.1.1.7 Inflate bladder.
7.1.1.8 Remove 5 1/2-in. bull plug from bottom 5 1/2-in. casing sub.
OPERATING PROCEDURE 7.2
INSTALLATION OF RESERVOIR PICK-UP ASSEMBLY
7.2.1 Reservoir pick-up assembly.
7.2.1.1 The 5 1/2-in. casing elevators with appropriate cable chokers
are used for pick-up assembly.
7.2.1.2 A crane is to be scheduled to move reservoir from assembly
stand to reservoir stand.
7.2.1.3 Elevators are connected to top 5 1/2-in. casing sub welded to
artificial reservoir housing.
OPERATING PROCEDURE 8.1
MIXING OF MUD ACCORDING TO OKLAHOMA CORPORATION
COMMISSION'S STANDARDS FOR WELL-PLUGGING
8.1.1 Mud must weigh at least 9.0 Ib./gal.
8.1.2 Mud must have funnel viscosity of 36 sec./qt. or more.
8.1.3 Mud is to be mixed with fresh water according to the following table:
Mud Type
#1 #2 #3 #4 #5
Funnel viscosity (sec/qt) 36 45 54 63 72
Weight, bentqnite (Ib/bbl) 11.06 13.01 14.96 16 91 18 86
Weight, barite (Ib/bbl) 28.39 26.95 25.50 24.06 22.61
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OPERATING PROCEDURE 8.2
HOMOGENIZATION OF DRILLING MUD
8.2.1 Drilling mud homogenization.
8.2.1.1 Activate mud pump with appropriate valves opened.
8.2.1.2 Set back-pressure valve to approximately 200 psi.
8.2.1.3 Circulate mud to and from mud tank.
8.2.1.4 Activate mud mixer in mud tank.
8.2.1.5 Operate for sufficient time, with mud pump and mud mixer activated
to mix mud thoroughly.
8.2.1.6 Terminate mixing when mud becomes a homogeneous
mixture. Refer to Operating Procedure 8.3.
OPERATING PROCEDURE 8.3
SAMPLING AND TESTING OF DRILLING MUD
8.3.1 Mud is sampled during circulation, while performing Operating
Procedures 8.2, 8.4, and 10.5.
8.3.2 Obtain a 2-qt. sample each time. Sample at beginning and end of operation
and at one-fourth the way, one-half the way, and three-quarters the way
through the operation.
8.3.3 Test mud according to API RP 13B, pages 4, 6, 8, 9, 19, 42 and 43.
OPERATING PROCEDURE 8.4
EMPLACEMENT OF DRILLING MUD IN CASING STRING
8.4.1 This procedure is same as emplacement of water, described in Ooeratina
Procedure 5.1. *
OPERATING PROCEDURE 8.5
REMOVAL OF DRILLING MUD FROM CASING STRING
8.5.1 This procedure described in Operating Procedure 15.1.
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OPERATING PROCEDURE 9.1
PLACEMENT OF RESERVOIR STAND
9.1.1 Removal of 2 3/8-in. tubing from casing.
9.1.1.1 Remove tubing fittings used to fill casing.
9.1.1.2 Pull 2 3/8-in. tubing with pulling unit.
9.1.1.3 Stack 2 3/8-in. tubing on rack.
9.1.2 Disassembly of 5 1/2-in. casing head.
9.1.2.1 Disconnect 5 1/2-in. casing-head assembly at 5 1/2-in. hammer union.
9.1.2.2 Place 5 1/2-in. casing-head assembly under pipe on rack.
9.1.3 Placement of reservoir stand.
9.1.3.1 Lift reservoir stand over wellbore.
9.1.3.2 Align anchor-bolt holes with pre-drilled Red Head anchors.
9.1.3.3 Make up anchor bolts.
9.1.3.4 Adjust screw jacks to receive artificial reservoir.
OPERATING PROCEDURE 9.2
PLACEMENT OF ARTIFICIAL RESERVOIR ON RESERVOIR STAND
9.2.1 Preparation of reservoir stand and casing string.
9.2.1.1 Place reservoir stand. Refer to Operating Procedure 9.1.
9.2.1.2 Fill casing string with drilling mud. Refer to Operating Procedure 8.4.
9.2.1.3 Check hammer union to mate with artificial reservoir.
9.2.1.4 Schedule crane to move artificial reservoir.
9.2.2 Preparation of reservoir for moving.
9.2.2.1 Disconnect instrumentation console and associated lines while
maintaining fluid in artificial reservoir.
9.2.2.2 Move environmental building to northeast comer of slab.
9.2.2.3 Place bladder in artificial reservoir between drilling-mud supply port
and water-injection test port, and inflate.
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9.2.2.4 Remove bull plug from bottom of artificial reservoir.
9.2.2.5 Move artificial reservoir to reservoir stand.
9.2.3 Moving artificial reservoir to reservoir stand.
9.2.3.1 Attach 5 1/2-in. casing elevators to crane
9.2.3.2 Connect elevators to 5 1/2-in. casing on top of artificial reservoir.
9.2.3.3 Pick up and move artificial reservoir to reservoir stand.
9.2.3.4 Pay particular attention to alignment of reservoir with casing string.
9.2.3.5 After alignment is obtained, screw hammer union together hand-tight.
9.2.3.6 Adjust screw jacks on reservoir stand to level artificial reservoir.
9.2.3.7 Tighten hammer union with sledge hammer.
9.2.3.8 Loosen and release crane from artificial reservoir.
9.2.3.9 Retrieve elevators from crane.
9.2.3.10 Re-check level of artificial reservoir.
OPERATING PROCEDURE 10.1
HOMOGENIZATION OF DRILLING MUD
10.1.1 This procedure described in Operating Procedure 8.2.
OPERATING PROCEDURE 10.2
DISPLACEMENT OF PACKER
10.2.1 Connect mud supply to bottom of reservoir.
10.2.2 Connect return line to horizontal leg of tee on top of reservoir.
10.2.3 Open all valves on upper tee.
10.2.4 Adjust bypass valve to place low-pressure mud supply in supply line.
Open supply valve below reservoir and allow mud to force packer slowly up
wellbore. Watch packer arrive at top by viewing through top valve
Screw fixture in packer to hold in place.
10.2.5 Hold packer in place; shut off supply valve and mud pump.
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10.2.6 Use packer to swab out mud above packer Remove hammer union and
then remove packer.
OPERATING PROCEDURE 10.3
ADJUSTMENT OF FLOW RATE AND BACK-PRESSURE
10.3.1 See Page 4.26 ff.of report for details
OPERATING PROCEDURE 10.4
MONITORING OF MUD-FILTRATE FLOW RATE
10.4.1 See page 4.26 ff.of report for details
OPERATING PROCEDURE 10.5
SAMPLING AND TESTING OF DRILLING MUD
10.5.1 This procedure described in Operating Procedure 8.3.
OPERATING PROCEDURE 10.6
SHUT-DOWN PROCEDURE AND LINE REMOVAL
10.6.1 See pages 4.26 ff. of report for details
10.6.2 Shut all valves in vicinity of mud pump - in both supply and return lines.
Shut valve in line connecting supply to reservoir and valve in line connecting
return to reservoir.
10.6.3 Remove upper line (return line) first and drain into buckets. Then pour into
effluent tank for disposal.
10.6.4 Repeat 10.6.3 for lower line.
OPERATING PROCEDURE 10.7
REFINED ADJUSTMENT OF PRESSURE TO PRESCRIBED MAGNITUDE
10.7.1 Check pressure in casing above artificial reservoir; if pressure is less than
desired under conditions of testing, increase regulator setting for
mud-column flow meter to desired value.
10.7.2 If pressure is more than desired under conditions of testing, use bleed-line
valve connecting line from top of mud column to effluent tank to reduce to
desired pressure.
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OPERATING PROCEDURE 11.1
MONITORING OF MUD COLUMN FOR DIFFERENTIAL PRESSURE,
PRESSURE AND TEMPERATURE
11.1.1 Data-acquisition system is activated during time mud is placed in well.
System is to continue monitoring mud from time well is full until equilibration
is recorded.
11.1.2 Data are recorded continuously on computer hard disk, but computer screen
is to be viewed during the first hour and each hour thereafter for 6 hr.,
then periodically until there is no apparent change in output of
differential-pressure transducer.
OPERATING PROCEDURE 11.2
MONITORING OF MUD COLUMN AT SIMULATED-DEPTH CONDITIONS
FOR DIFFERENTIAL PRESSURE, PRESSURE, AND TEMPERATURE '
11.2.1 After reservoir is placed over well, all systems are connected, and mud is
put under simulated well pressure; the effect of pressure on equilibration will
be monitored.
11.2.2 Use Operating Procedure 11.1.2 to monitor well under pressure.
OPERATING PROCEDURE 12.1
ACTIVATION OF SALT-WATER INJECTION SYSTEM
12.1.1 Salt water is placed in the two salt-water accumulators, using salt-water
tank and transfer pump.
12.1.2 Adjust regulator on instrument console to supply salt-water accumulators
with desired injection pressure.
OPERATING PROCEDURE 12.2
MONITORING AND RECORDING COMPREHENSIVE PRESSURE
DIFFERENTIALS, PRESSURES AND FLOW RATES.
12.2 1 Data are recorded on hard disk of computer; screen is to be monitored
several times each day. If a significant event occurs, then floppy-disk file
will be used to investigate the activity.
12.2.2 If a 0.3-gpm flow rate is detected, test is complete. If a low rate or no rate
is detected, then a higher injection pressure is set.
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OPERATING PROCEDURE 12.3
INCREASING INJECTION PRESSURE IN RESPONSE TO UNDETECTABLE
FLOW FROM RESERVOIR
12.3.1 If no flow into reservoir is detected, and no gradient change is detected in
transducers just above injection zone, then injection pressure is increased.
12.3.2 If a gradient change occurs in pressure transducers above injection zone,
then movement of gradient change is to be monitored. Time required for'
gradient change to get to top will be determined. If time has expired
and no flow rate is detected, then injection pressure will be increased.
OPERATING PROCEDURE 12.4
INCREASING INJECTION PRESSURE IN RESPONSE TO LOW RATES OF
FLOW FROM RESERVOIR
12.4.1 If a low flow-rate is detected, this rate will be monitored for 24 hr.,
to determine the time history. After that time, injection pressure will be
increased and monitoring will continue.
12.4.2 Procedure 12.4.1 will be repeated until flow-rate attains a level of 0.3 gpm.
OPERATING PROCEDURE 12.5
TERMINATION OF INJECTION IN RESPONSE TO MAXIMIZED
FLOW OR PRESSURE
12.5.1 When flow-rate is 0.3 gpm or greater, tests are considered to be complete-
pressures are to be relieved from the system. Computer-data acquisition is
terminated after pressures are relieved.
OPERATING PROCEDURE 13.1
REMOVAL OF INSTRUMENTATION FROM ARTIFICIAL-RESERVOIR HOUSING
13.1.1 Only the instrumentation that is not securely attached to housing must be
removed - such as the two differential-pressure processing units on top of
housing.
13.1.2 Remove all electrical connections from multiplexers to instrumentation
and from multiplexers to computer.
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OPERATING PROCEDURE 13.2
DISCONNECTING RESERVOIR HOUSING FROM CASING STRING
13.2.1 Pump mud from supply line located under reservoir-housing and place it in
effluent tank.
13.2.2 Disconnect effluent line from reservoir. Also, remove the mud column from
above reservoir-housing, using forklift boom and hook; bring it out through
roof of building.
13.2.3 Remove lean-to from building and take instrument console out of building.
13.2.4 Lift building off reservoir-housing with forklift and boom. Hook into four
lifting eyes attached to building.
13.2.5 Knock off the hammer union connecting casing and reservoir housing.
OPERATING PROCEDURE 13.3
INSTALLATION OF RESERVOIR PICK-UP ASSEMBLY AND MOVEMENT OF
RESERVOIR HOUSING
13.3.1 Call for crane services to move artificial reservoir.
13.3.2 Place crane on concrete pad so that it can just swing boom to pick-up and
replace housing.
13.3.3 Pick reservoir housing up using 5 1/2-in. casing tongs.
13.3.4 Place housing on assembly stand and secure.
OPERATING PROCEDURE 14.1
REMOVAL OF ARTIFICIAL RESERVOIR FROM HOUSING
14.1.1 Remove all vertical flow lines that connect from top of housing to bottom of
housing and that would hinder removal of top flange.
14.1.2 Remove all bolts connecting the two top flanges.
14.1.3 Use forklift to remove top flange, being careful to not disturb gasket.
14.1 4 Remove all bolts connecting the two bottom flanges.
14.1.5 Attach cables to top of flange and to forklift
14.1.6 Lift flange; artificial reservoir should remain on bottom blind flange.
If not, a set of rail ties, of dimensions that will fit on inside of housing, will be
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placed on the ground. Housing will be dropped purposefully on ties, to force
artificial reservoir out of housing.
OPERATING PROCEDURE 14.2
MAPPING AND LABELING OF RESERVOIR SURFACE FOR
RANDOM SAMPLING
14.2.1 Divide artificial reservoir intp pie sections; label each according to radial
position, depth into reservoir and azimuth. Assign a code number for each
section
14.2.2 Sample reservoir by random-number coding. Sample size equal to or more
than 30
14.2.3 Take channel samples at specified locations, from top to bottom on
periphery of artificial reservoir. Mix and sample randomly.
14.2.4 Take stratified samples (according to lifts) at periphery, coring toward
the borehole.
14.2.5 Spot samples will be taken from any location that can give suitable access.
OPERATING PROCEDURE 14.3
COLLECTION OF RANDOM SAMPLES
14.3.1 This procedure described in Operating Procedure 14.2.
OPERATING PROCEDURE 14.4
LABELING AND STORAGE OF SAMPLES
14.4.1 Reservoir samples are to be labeled with the following information-
Location (radius, depth and azimuth)
Code number
Date
Test number
Test duration
Simulated reservoir depth
Simulated injection depth
Mud pressure at reservoir depth
Injection pressure at injection depth
Type of injection fluid
14.4.2 Samples will be stored at the School of Geology.
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OPERATING PROCEDURE 15 1
DISPLACING DRILLING MUD WITH WATER
15.1.1 Run 2 3/8-in. tubing into 5 1/2-in. casing and set it on bottom. Make sure
seating nipple is placed on bottom joint.
15.1.2 Connect water pump to 2 3/8-in. tubing. Connect wellhead annulus to
effluent tank.
15.1.3 Pump water through tubing to force mud out of casing into tank. Continue
pumping until clean water comes out of line
OPERATING PROCEDURE 15.2
CALIBRATION CHECK OF SENSORS
15.2.1 This procedure described in Operating Procedure 5.3.
OPERATING PROCEDURE 15.3
DISPLACING WATER WITH AIR
15.3.1 Disconnect water line and line to tank. Connect high-volume air compressor
to annulus of wellhead. Connect plastic flow line to 2 3/8-in. tubing and run
flow line to ditch.
15.3.2 Shut valve on top of 2 3/8-in. tubing and pressure annulus with air, sufficient to
lift water from maximum depth Operate until all water is out of casing
(detectable when air flows from line).
15.3.3 Pull tubing, making sure that if some of joints are still "wet," water is kept
from going back into casing.
OPERATING PROCEDURE 15.4
SHUT-DOWN OF COMPUTERIZED DATA-ACQUISITION SYSTEM
15.4.1 Deactivate sensors; stop computer data-acquisition program. Observe file
name and size of file on directory.
15.4.2 Remove data disk from 44-megabyte hard drive and record test designation.
Shut off computer.
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OPERATING PROCEDURE 16.1
DOCUMENTATION OF SOFTWARE FOR REDUCTION OF DATA
16.1.1 Document software for reduction of data by defining all variables
used in program.
16.1.2 Use comment statements to guide users through source program, to identify
pertinent steps.
16.1.3 Describe reduction steps and show by example.
OPERATING PROCEDURE 16.2
DOCUMENTATION OF SOFTWARE FOR ANALYSIS OF DATA
16.2.1 Show software documentation for Quattro Pro and Timeslab
16.2.2 Itemize particular sections of these software packages used to analyze
data and show an example.
OPERATING PROCEDURE 16.3
METHODS FOR RECORDING OF DATA
16.3.1 Make appropriate forms for type of test being conducted and record data
by hand to spot-check computer results.
16.3.2 Data are recorded on 44-megabyte removable hard drive. Data files are
closed at midnight with a new file opened for each day. Files are numbered
incrementally.
OPERATING PROCEDURE 16.4
METHODS FOR SECURE STORAGE OF DATA.
16.4.1 Store all important data in safe, in Development Engineer's office.
16.4.2 Duplicates of data in safe will be placed in file in Project Director's office.
OPERATING PROCEDURE 16.5
METHODS OF REDUCING DATA
16.5 1 Raw data from each sensor will require a calibration curve to reduce data
to engineering units.
16.5.2 Sub-programs for Quattro Pro are one means of reducing data
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to usable terms.
16.5.3 Programs for data reduction to be written in "C" and Basic languages for those
cases in which analysis involves files too large for Quattro Pro.
16.5.4 Average values over periods of time (determined by viewing segments of
data plotted on screen of the computer monitor) are to be used in place
of single values, when slope of data string is zero and data variations are not
greater than estimated error.
16.5.5 Data analysis will involve regression techniques. Time-series analysis may
be used to determine correlation of different events occurring
simultaneously or with time-lag.
OPERATING PROCEDURE 16.6
METHODS FOR VALIDATING DATA
16.6.1 Total flow from injection flow meter and mud-column flow meter must equal
that from effluent flow meter. If not, suspicion of a leak is in order.
16.6.2 Water in system before testing and after testing provides check on calibration
of instruments for data-validation.
16.6.3 Readings from pressure-transducers mounted down-hole are to be used
to validate differential-pressure transducer readings. These are for only the
differential-pressure transducers that are bounded by pressure transducers
on both ends.
16.6.4 Theoretical calculations are to be made, to be compared with measured
pressure and differential-pressure values, to determine whether data are
within the range of expected values.
16.6.5 Pressure gauges are placed in the system, to be used for comparison with
those pressure transducers associated with the gauges.
16.6.6 Pressure gradients of mud will be plotted. The interpolated curve will be
used to determine the amount of mud required to be mixed in water,
to achieve the gradient. These calculations will be compared with
amounts of mud actually put into the system. These values should be equal.
OPERATING PROCEDURE 16.7
DEFINITION OF DATA-QUALITY INDICATORS
16.7 1 If continuity from flow-meter measurements shows total volume within
1 percent error, data are considered to be of acceptable quality.
16.7.2 If values from calibration with water (a) prior to the test and (b) subsequent to
the test compare within 1 percent, data are considered to be of acceptable
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quality.
16.7.3 If those values from Operating Procedure 16.6.6 are within 2 percent,
data are considered to be of acceptable quality.
16.7.4 If those values from Operating Procedure 16.6.4 are within the range of
calculated limits, then the data are acceptable.
OPERATING PROCEDURE 16.8
METHODS FOR EVALUATING QUALITY OF DATA
16.8."1 Compare flow volume from effluent flow meter with sum of values from
injection flow meter and mud-column flow meter, to determine percent
variation. Compare to the percent error allowed in Operating Procedure
16.7.1.
16.8.2 Reduce data from (a) prior to test and compare to (b) data subsequent to test
with water in the system, to determine percent variation. Compare to the
criteria in Operating Procedures 16.7.2.
16.8.3 Calculate mud required to give pressure gradient measured during the test
and compare calculation with total mud placed in system, to determine percent
variation. Compare percent variation to criteria shown in Operating
Procedure 16.7.3.
16.8.4 Where possible, make theoretical calculations using an upper and lower limit
of expected data and compare calculations to actual data. Use Operating
Procedure 16.7.4 to judge results.
OPERATING PROCEDURE 16.9
METHODS FOR PRESENTING DATA
16 9.1 Data will be provided in data files, ASCII format, for viewing on monitor.
16.9.2 Pertinent data will be presented in tabular format.
16.9.3 Dependent variables will be plotted with respect to independent variables
to show their relationships.
16.9.4 Statistical parameters will be presented in tabular format.
OPERATING PROCEDURE 16.10
REPORTING OF CONCLUSIONS
16.10.1 Define as much of the performance envelope as data allow to show
effects of injection on plugged wells.
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16.10.2 Provide lists of developments and knowledge, which will be guidelines for
future activities
OPERATING PROCEDURE 17.1
MULTIPLE-CORE MUDCAKE-AND-PERMEABILITY TEST PROCEDURE
17.1.1 Test for permeability to water.
17.1.1.1 Select cores by defined criteria.
17.1.1.2 Put cores in 1000-ml. beaker; cover cores with distilled water.
17.1.1.3 Place beaker with cores in altitude chamber; evacuate chamber to
90,000 ft. for approximately 1 hour. (Caution: Do not let the water
freeze.)
17.1.1.4 Take wet-weights of cores using OHAUS scale; record in M&P
data book
17.1.1.5 Place cores in rubber core-holders. Make sure that bottoms of cores
are flush with bottoms of rubber holders.
17.1.1.6 Coat outsides of rubber core-holders with light coat of white grease.
17.1.1.7 Assemble photocell assembly on core-holder cap.
17.1.1.8 Hold photocell and core-holder cap assembly right-side-up and
fill tube with water.
17.1.1.9 Open drip valve until bottom of drip tube is full of water;
then shut valve.
17.1.1.10 Refill assembly with water.
17.1.1.11 Slide core rubber (with core inside) into subassembly.
17.1.1.12 Screw core-holder caps pnto subassembly to hold core Caution:
Do not break photocell wires.
17.1.1.13 Tighten caps with cap wrench.
17.1.1.14 Record core locations in subassemblies, in M&P data book.
17.1.1.15 Take dry-weights of 400-ml. beakers; record in M&P data book.
171.1.16 Place 400-ml. beaker under each drip tube.
17.1.1.17 Place 400-ml. beaker under drip tube 3.3 directly on the OHAUS
scale; tare the scale.
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17.1.1.18 Close valves 42, 49, 50, 60, 61, 68.
17.1.1.19 Fill subassemblies with water using 1/4-in. flexible hose.
17.1.1.20 Close nitrogen-inlet valves 46, 56, 65.
17.1.1.21 Open pressure-gauge valves 54 and 57.
17.1.1.22 Start Mud Program on computer and save to disk "D".
o Set proper time and date.
o At "C" prompt type "MUD;" press .
o Press to continue.
o Press "Y" to save to disk.
o Save to "0" disk.
o Enter file name. (Date+H2O)
o Press "S" and "Enter" to start program
17.1.1.23 Adjust nitrogen pressure to 29.4 psi. on P-50, on computer screen.
17.1.1.24 Open nitrogen-inlet valves 46, 56, 65.
17.1.1.25 Open drip-tube valves.
17.1.1.26 Close each drip tube when beaker fills to 200 ml:
17.1.1.27 When all drip tubes are closed, close nitrogen-inlet
valves 46, 56, 65.
17.1.1.28 Press to exit computer program.
17.1.1.29 Take wet-weights of 400-ml. beakers; record with manually
recorded data, in M&P data book.
17.1.1.30 Drain and clean 400-ml. beakers.
17.1.2 Mud-cake buildup.
17.1.2.1 To weigh constituents for 9-lb./gal., 36-sec.-viscosity mud
(Marsh Funnel test):
o Zero scale with 5-gal. bucket on scale
o Weigh 30 Ibs. of bentonite into 5-gal. bucket
o Weigh 60 Ibs. of barite into 5-gal. bucket.
17 1.2.2 Valves in EPA Building: valve 42 closed, valve 41 open-
valve 51 closed. '
17.1.2.3 Valves on mud-pump plumbing:
o Valve on bottom of hopper closed.
o Suction valve for pump open.
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o Valve to large mud tank closed.
o Drain-valves to system drain closed.
o Discharge straight through valve on Baird pressure-relief valve
closed; down valve open.
o System-line valve at "B" open.
o Jet-system mixer-valve open.
o Down side of jet-mixer valve closed.
o Main throttle valve all the way open.
o Effluent valve closed.
o Drain side of effluent valve closed.
o Calibration-line valve open.
o Valve on 80-bbl. mud tank closed.
o Mud-hopper return valve open.
MA.2 A Fill hopper with 67.7 gal. of water, using water hose and flow meter.
171.2.5 Start circulating through hopper and jet-mixer. Make sure the valves
are set, so mud will not circulate through multi-core permeameter
in EPA Building.
17.1.2.6 Pour bentonite and barite into jet-mixer.
17.1.2.7 Circulate for 30 minutes.
17.1.2.8 Divert flow into EPA Building.
17.1.2.9 Open line-valve to EPA Building.
17.1.2.10 Close jet-mixer valve about halfway.
17.1.2.11 Take mud samples for mud properties, through sample-port Valve
40 in EPA Building (flush port tube into separate container).
17 1.2.12 If mud is 9 Ib./gal and 36-viscosity, continue; if not add enough
bentonite and barite to reach these standards.
17.1.2.13 Open valve 51 (throttling valve).
17 1.2.14 Close valve 54 (nitrogen-inlet valve).
17.1.2.15 Adjust nitrogen to 50 psi. with subassembly valves closed.
17.1.2.16 Adjust primary choke valve to 50 psi at gauge on mud pump.
17.1.2.17 Set mud-bypass valve (valve to jet-mixer) to adjust flow rate to
19.5gpmat 14.7 psi.
171.2.18 Check pressure at pump.
17.1.2.19 Start Mud Program on computer and save to disk "D".
o Set proper time and date.
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o At "C" prompt, type "MUD;" press .
o Press to continue.
o Press "Y" to save to disk.
o Save to "D" disk.
o Enter file name. (Date+MCB)
o Press "S" and to start program.
17.1.2.20 Divert flow through M&P system.
o Throttling-valve 51 full open.
o Open ball valves 68, 61, 60, 50, 49, 42.
o Close crossover-valve 41.
o Turn off nitrogen valve 54.
o Open nitrogen-inlet valve 65 to subassembly 3.
o Close nitrogen bottle.
17.1.2.21 (At this point, mud will circulate through subassemblies.) Open
drip-tube valves 44, 45, 47, 53, 55, 58, 63, 64, 66.
17.1.2.22 Run mud-cake build-up for 24 hr., keeping pressure at 50 psi by
adjusting choke valve. Attendent must be on duty throughout
mud-cake build-up.
17.1.2.23 Manually record mud-cake build-up data every hour as follows:
o Start-up time.
o General permeability of cores.
o Mud temperature.
o Computer time.
o Drip time.
o Pressure.
o Weight on OHAUS Scale.
17.1.2.24 Create QUATTRO PRO spreadsheet with manually recorded data.
17.1.2.25 Create QUATTRO PRO graph with manual data. (Note- Computer
time must be divided by 3600 to convert it to hours!) Graph should
have run-time in hours on X-axis, and drip-time in seconds on
Y-axis. Legend should be on upper-right-side of plot, identifying
each curve. File name and permeability should be on both
spreadsheet and graph.
17.1.2.26 Fill 1-gal. jug with mud from mud-port in EPA Building; record data
and time on jug.
17.1.2.27 Fill two mud-settling chambers, on bottom and one from the top
Record date, time and whether the chamber was filled from top
or bottom.
17.1.2.28 Run water-loss test, using mud kit. Record water loss and
mud-cake thickness on data sheet, with data taken manually at
drip-tube 3.3.
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17.1.2.29 Run Fann Viscometer test on mud and record data in M&P
data book.
17.1.2.30 Divert mud from subassemblies and flush with clean water.
17.1.2.31 At least 3 hrs. before terminating mud-cake build-up test fill the
fresh-water tank to at least 1 ft. above suction valve.
17.1.2.32 Adjust nitrogen pressure to 50 psi, with valve 54 closed.
17.1.2.33 Open effluent line.
17.1.2.34 Close mud-return line (not mud-mixing valve!).
17.1.2.35 Draw mud down to top of cone in mud hopper.
17.1.2.36 Open fresh-water inlet valve to pump.
17.1.2.37 Close suction valve on mud hopper.
17.1.2.38 Circulate water through subassemblies until mud hopper is almost
full, or until clean water returns to hopper.
17.1.2.39 Open by-pass valve 41.
17.1.2.40 Close ball valves 42, 49, 50, 60, 61, 63.
17 1.2.41 Close throttle valve 51.
17.1.2.42 Close drip valves 44, 45, 47, 53, 55, 58, 63, 64 and 66
Clean dnps off drip-tubes.
17.1.2.43 Open choke-valve fully.
17.1.2.44 Close jet-mixing valve before hopper overflows.
17.1.2.45 Exit data-acquisition program by pressing .
17.1.2.46 Take wet^weight of 400-ml. beakers; record with the
manually-recorded data.
17.1.2.47 Record pH of filtrate water that is in beakers.
17.1.2.48 Clean and dry 400-ml. beakers.
17.1.2.49 Flush mud pump with fresh water and pump mud into the effluent
tank and clean equipment.
17.1.3 Preparation for water in-situ test.
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17.1.3.1 Place 400-ml. beakers under drip-tubes.
17.1.3.2 Set time and date on data-acquisition computer.
17.1.3.3 Check time and date on data-acquisition computer.
17.1.3.4 Start Mud Program on computer and save to disk "D".
o At "C" prompt, type "MUD;" press .
o Press to continue.
o Press "Y" to save to disk.
o Save to "D" disk. .
o Enter file name. (Date+INS)
o Press "S" and to start program.
17.1.3.5 Make sure that each photocell reads "0" (no activity) on the
computer. All nitrogen-inlet-valve indicators (L,M,R on the
computer screen) should read "0" for "shut."
17.1.3.6 Open nitrogen valve 54.
17.1.3.7 Adjust nitrogen pressure to 50 psi - the P-500 reading on the
computer.
17.1.3.8 Open nitrogen-supply valves 46, 56, 65 to each
subassembly. (The L,M,R indicators on the computer should now
have 1's, indicating that the valves are open).
17.1.3.9 Open drip-valves 44, 45, 47, 53, 55, 58, 63, 64, 66.
17.1.3.10 Run in-situ test for 72 hrs. keeping pressure at 50 psi by adjusting
the nitrogen regulator.
17.1.3.11 Record data manually every hour, as follows:
o Start-up time.
o Temperature of Subassembly 3.3.
o Computer time.
o Drip time.
o Pressure.
o Weight on OHAUS scale.
17.1.3.12 Create a QUATTRO PRO spreadsheet with the manually recorded
data.
17.1.3.13 Create a QUATTRO PRO graph with the manually recorded data.
(Computer time must be divided by 3600 to convert it to hours.)
Graph should have run-time in hours on the X-axis, and drip-time
in seconds on the Y-axis. A legend should be at the upper-right-
hand side of the plot, to identify each curve. File name and
permeability should be on both spreadsheet and graph.
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17.1.3.14 To end the in-situ test, close nitrogen inlet.
17.1.3.15 Close drip valves 44, 45, 47, 53, 55, 58, 63, 64, and 66.
Clean drips off drip-tubes.
17.1.3.16 Exit data-acquisition program by pressing .
17.1.3.17 Close valve on nitrogen bottle.
17.1.3.18 Slowly open bleed valve at nitrogen regulator on nitrogen bottle
to relieve pressure on nitrogen-supply line.
17.1.3.19 Slowly open valves 43, 52, 62, the top ports on each subassembly
to relieve pressure on subassemblies.
17.1.3.20 Slowly open valves 48, 59, 67, to drain water from subassemblies.
17.1.4 Remove cores and make photographs.
17.1.4.1 Remove drip-tube and photocell.
17.1.4.2 Remove core-holder cap.
17.1.4.3 Remove rubber core-holder, using knrfe.
17.1.4.4 Place core (still in core-rubber) on clean white sheet of paper that is
marked with core drip-tube number and M&P test date.
Take photograph of core in the core-holder rubber, from horizontal
position, with ruler marked in thirty-seconds of an inch lying against
core-rubber. " **
17.1.4.5 Remove core from rubber core-holder. Place core'back on the
paper and take photograph from above the core, with ruler lying flat.
17.1.4.6 Take photograph from horizontal position. Make sure angle is 90
degrees to core. Ruler should be in vertical position, so mud-cake
thickness can be observed clearly, by comparison with
32's-of-an-inch scale.
17.1.4.7 Place cores in plastic film containers with test date and
corresponding core-holder number marked on lid.
17.1.4.8 Place unusable cores in core-rubbers and install in subassembly.
17.1.4.9 Install core-holder caps.
17.1.4.10 Close mud-hopper suction valve.
17.1.4.11 Open fresh-water suction valve on fresh-water tank.
17.1.4.12 Close valve 41 and open valves 42, 49, 50, 60, 61, 68 and 51
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17.1.4.13 Open discharge valve to effluent tank.
17.1.4.14 Start mud pump.
17.1.4.15 Circulate fresh-water through subassemblies.
17.1.4.16 Clean mud pump, and mud hopper and equipment.
17.1.4.17 Stop pump.
17.1.4.18 Open mud-system drain valves.
17.1.4.19 Remove core-holders.
17.1.4.20 Clean insides of subassemblies with brush.
OPERATING PROCEDURE 17.2
PREPARATION FOR MUD-CAKE-AND-PERMEABILITY TEST
17.2.1 Measure dry weight of each test core.
17.2.2 Measure volume of each test core.
17.2.3 Complete gas-permeameter test for each core.
17.2.4 Measure wet-weight of each core.
17.2.5 Complete liquid-permeameter test for each core.
OPERATING PROCEDURE 17.3
RECORDING NUMBERS OF CORES
17.3.1 Information shown below is to be recorded in M&P-test data record, Section 1
M&P Subassemblv-1
Core Number Core-holder 1.1, Discharge-tube valve 44.
Core Number Core-holder 1.2, Discharge-tube valve 45.
Core Number Core-holder 1.3, Discharge-tube valve 47.
M&P Subassemblv-2
Core Number Core-holder 2.1, Discharge-tube valve 53.
Core Number Core-holder 2.2, Discharge-tube valve 55.
Core Number Core-holder 2.3, Discharge-tube valve 58.
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M&P Subassemblv-3
Core Number Core-holder 3.1, Discharge-tube valve 63.
Core Number Core-holder 3.2, Discharge-tube valve 64.
Core Number Core-holder 3.3, Discharge-tube valve 66.
17.3.2 M&P Subassemblies are numbered from right to left. Core-holders are
numbered from right to left. Example: M&P Subassembly 3 contains
core-holders 3.1, 3.2, and 3.3.
OPERATING PROCEDURE 17.4
MEASURING DRY-WEIGHTS OF BEAKERS
17.4.1 Place empty beaker on OHAUS scale.
17.4.2 Record dry weight in M&P-test data record, Section 2, in "dry-weight" column.
Note: Beaker-numbers should correspond with numbers of core-holders and
subassemblies.
17.4.3 Use format shown below.
Dry Weight Wet Weight
(grams) (grams)
M&P Subassemblv 1
Beaker 1.1.
Beaker 1.2:
Beaker 1.3:
M&P Subassemblv 2
Beaker 2.1
Beaker 2.2:
Beaker 2.3:
M&P Subassemblv 3
Beaker 3 1:
Beaker 3.2:
Beaker 3.3.
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OPERATING PROCEDURE 17.5
PLACEMENT OF CORES INTO RUBBER CORE-HOLDER SLEEVES
17.5.1 Coat outsides of rubber core-holder sleeves with petroleum jelly.
This includes top beveled surface.
17.5.2 Take core from saturation vessel with tongs.
17.5.3 Place core (top end up) on core-mounting plate.
17.5.4 Place core-holder sleeve over core and press down on sleeve to insert core
into sleeve. Caution: Top of sleeve is beveled; it should be flush with top
of core. Bottom of core-holder and bottom of core-holder sleeve
should be flush.
17.5.5 Repeat steps 17.5.1 to 17.5.4 for all cores used in test.
OPERATING PROCEDURE 17.6
PLACEMENT OF CORE AND CORE-HOLDER CAP ONTO M&P SUBASSEMBLY
17.6.1 Check core-holder valve; it should be closed.
17.6.2 Fill nipple-end-valve chamber of core-holder cap with water to a level
with top of Teflon disk.
17.6.3 Place rubber core-holder sleeve on Teflon disk in metal core-holder
cap, beveled edge up. Caution: bottom of the core should be flush with
bottom of core-holder sleeve.
17.6.4 Mount core and core-holder cap onto core holder. Tighten cap finger-tight
Then tighten snugly with spanner wrench.
17.6.5 Mount lower-discharge-tube tip with photocell onto discharge-tube valve
Use 9/16 open-end wrench to tighten. Caution: Photocell line must be
connected to computer-input line.
17.6.6 Repeat steps 17.6.1 through 17.6.5 for each core-holder used in test.
OPERATING PROCEDURE 17.7
PLACEMENT OF BEAKERS UNDER DISCHARGE-TUBES
ON M&P SUBASSEMBLIES
17.7.1 Place 80-ml beakers beneath core-holders. Beaker-number should match
subassembly-number and core-holder number.
17.7.2 Place "OHAUS scale" beneath core-holder 3.3, M&P Subassembly 3.
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17.7.3 Put 80-ml beaker 3.3 on "OHAUS scale".
17.7.4 Push tare button on "OHAUS scale".
OPERATING PROCEDURE 17.8
SETTING VALVE-POSITIONS ON M&P SUBASSEMBLIES
17.8.1 If nine cores are to be tested, then complete the steps 17.8.2 through 1784
If six cores are to be tested, then complete steps 17.8.3 and 1784
If three cores are to be tested, then complete step 17.8.4.
17.8.2 Set valves on M&P Subassembly 1 (right end).
17.8.2.1 Close inlet-isolation valve (valve 42).
17.8.2.2 Open bleed-port valve (valve 43).
17.8.2.3 Check discharge-tube valve (valve 44 closed).
17.8.2.4 Check discharge-tube valve (valve 45 closed).
17.8.2.5 Close injection-port valve (valve 46).
17.8.2.6 Check discharge-tube valve (valve 47 closed).
17.8.2.7 Open drain-and-fill valve (valve 48).
17.8.2.8 Close outlet-isolation valve (valve 49).
17.8.3 Set valves on M&P Subassembly 2 (center).
17.8.3.1 Close inlet-isolation valve (valve 50).
17.8.3.2 Open bleed-port valve (valve 52).
17.8.3.3 Check discharge-tube valve (valve 53 closed).
17.8.3 4 Check discharge-tube valve (valve 55 closed).
17.8.3.5 Close injection-port valve (valve 56).
17.8.3.6 Check discharge-tube valve (valve 58 closed).
17.8.3.7 Open drain-and-fill valve (valve 59).
17.8.3.8 Close outlet-isolation valve (valve 60).
17.8.4 Set valves on M&P Subassembly 3 (left end).
17.8.4.1 Close inlet-isolation valve (valve 61).
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17.8.4.2 Open bleed-port valve (valve 62).
17.8.4.3 Check discharge-tube valve (valve 63 closed).
17.8.4.4 Check discharge-tube valve (valve 64 closed).
17.8.4.5 Close injection-port valve (valve 65).
17.8.4.6 Check discharge-tube valve (valve 66 closed).
17.8.4.7 Open drain-and-fill valve (valve 67).
17.8.4.8 Close outlet-isolation valve (valve 68).
OPERATING PROCEDURE 17.9
FILLING M&P SUBASSEMBLY CHAMBER WITH WATER
17.9.1 If nine cores are used, then complete steps 17.9.2 through 17.9 4 If six
cores are used, then complete steps 17.9.3 and 17.9.4. If three cores
are used, then complete step 17.9.4.
17.9.2 Fill M&P Subassembly-1 chamber with water.
17.9.2.1 Connect copper drain-line to bleed-port valve (valve 43)
Tighten with 9/16-in. open-end wrench.
17.9.2.2 Place container under copper drain-line to catch overflow water
when chamber is full.
17.9.2.3 Connect plastic water-supply-line to drain-and-fill valve (valve 48)
Tighten with 9/16-in. open-end wrench.
17.9.2.4 Open water-supply-line valve on plastic hose.
17.9.2.5 When water flows out of the copper drain-line connected to
valve 43, close water-supply-line valve.
17.9.2.6 Close drain-and-fill valve (valve 48).
17.9.2.7 Close bleed-port valve (valve 43).
17.9.2.8 Disconnect plastic water-supply-line from valve 48.
17.9.2.9 Remove copper drain-line from bleed-port valve (valve 43).
17.9.3 Fill M&P Subassembly-2 chamber with water.
17.9.3.1 Connect copper drain-line to bleed-port valve (valve 52)
Tighten with 9/16-in. open-end wrench.
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17.9.3.2 Place container under copper drain-line to catch overflow
water when chamber is full.
17.9.3.3 Connect plastic water-supply-line to drain-and-fill valve (valve 59).
Tighten with 9/16-in. open-end wrench.
17.9.3.4 Open water-supply-line valve on plastic hose.
17.9.3.5 When water flows out of the copper drain-line connected to valve 52,
close water-supply-line valve.
17.9.3.6 Close drain-and-fill valve (valve 59).
17.9.3.7 Close bleed-port valve (valve 52).
17.9.3.8 Disconnect plastic water-supply-line from valve 59.
17.9.3.9 Remove copper drain-line from bleed-port valve (valve 52).
17.9.4 Fill M&P Subassembly-3 chamber with water.
17.9.4.1 Connect copper drain-line to bleed-port valve (valve 62).
Tighten with 9/16-in. open-end wrench.
17.9.4.2 Place container under copper drain-line to catch overflow water
when chamber is full.
17.9.4.3 Connect plastic water-supply-line to drain-and-fill valve (valve 67).
Tighten with 9/16-in. open-end wrench.
17.9.4.4 Open water-supply-line valve on plastic hose.
17.9.4.5 When water flows out of the copper drain-line connected to
valve 62, close water-supply-line valve.
17.9.4.6 Close drain-and-fill valve (valve 67).
17.9.4.7 Close bleed-port valve (valve 62).
17.9.4.8 Disconnect plastic water-supply-line from valve 67.
17.9.4.9 Remove copper drain-line from bleed-port valve (valve 62).
17.9.4.10 Store plastic water-supply-line. Place water container and
wrench where they will not interfere with test.
17.9.4.11 All photocells must be connected to computer input line.
This applies to photocells on all subassemblies. If a photocell is
disconnected from computer input line, computer will interpret
that the photocell is sending information.
F59
-------
OPERATING PROCEDURE 17.10
ACTIVATE COMPUTER: M&P SOFTWARE OPERATION
17.10.1 Turn data-acquisition switch on.
17.10.2 Turn on AND scale.
17.10.3 Turn on OHAUS scale. Caution; If AND and OHAUS scales are not turned
on, then the computer system may lock up.
17.10.4 Turn on data-acquisition monitor.
17.10.5 Turn on computer.
17.10.6 At "C" prompt, type "MUD" and press key.
17.10.7 At computer prompt: "IS SETTING CORRECT? (Y/N)?11,
type "Y" if "HEX 220" is shown.
17.10.8 At computer prompt: "SAVE DATA TO DISK (Y/N)?", type "N."
17.10.9 Adjust nitrogen pressure to 2 Atmospheres.
17.10.9.1 "PSO" prompt on computer screen should be "29.4 psi."
17.10.9.2 Nitrogen pressure is regulated at tank, by pressure-regulating
valve. Adjust nitrogen pressure to 29.4 psi by secondary
pressure-regulating valve (which is on regulators, at nitrogen
tank). Turn regulator valve to right, to increase pressure.
17.10.9.3 If nine cores are used, complete steps 17.10.9.4
through 17.10.9.6. If six cores are used, complete steps
17.10.9.5 and 17.10.9.6.If three cores are used,
complete step 17.10.9.6.
17.10.9.4 Slowly open injection-port valve on M&P Subassembly 1
(valve 46).
17.10.9.5 Slowly open injection-port valve on M&P Subassembly 2
(valve 56).
17.10.9.6 Slowly open injection-port valve on M&P Subassembly 3
(valve 65). '
17.10.9.7 Allow nitrogen-pressure to stablize at 29.4 psi.
17.10.9.8 At computer prompt "WHICH DRIVE (A, B, C....)?", type "C "
Note: Drives "A" and "B" are slow when storing data. Therefore
if high speed is needed, use "C" drive.
F60
-------
17.10.9.9 At computer prompt "WHAT DATA FILE WOULD YOU LIKE TO
USE?" Type (File Name) and (Number). Note: Do not type
extension to file name; extension is assigned automatically.
Caution: Review log sheet to insure that file name and number
are not duplicated.
17.10.9.10 Record file name on log sheet. Extension ".ANA" signifies analog
data. Extension ".DIG" signifies digital data.
17.10.9.11 At computer prompt "(S)TART THE PROGRAM OR (W)EIGH
THE SAMPLE?", type "S."
17.10.9.12 At computer prompt "RE-ZERO SCALE? (Y/N)?",
type "Y" if you want to re-zero both the AND and the OHAUS
scales. Type "N" if the current scale-settings are acceptable.
17.10.9.13 At computer prompt "PROCEED (Y/N)?11, Type "Y", if you want to
return to the beginning of the program.
17.10.9.14 Check data shown on monitor during test.
P500 =00.0 psi
Nitrogen pressure at (right) pressure transducer.
P50 =00.0 psi
Nitrogen pressure at second pressure transducer.
Pressure should be 29.4 psi.
THERM =00.0 dea. F
Temperature of mud or water in return line. (Temperature
measured by probe near end of line, near computer.)
TEMPI: =00.Odea. F
Temperature measured by by thermocouple at left end of
multicore-pemneameter-1 chamber.
TEMP 2: =00.0deo. F
Temperature measured by thermocouple at left end of multicore-
permeameter-2 chamber.
TEMP 3: =00.0 deo. F
Temperature measured by thermocouple at left end of multicore-
permeameter-3 chamber.
COM2: =00.0 a
F61
-------
OHAUS scale provides continuous measurement of weight of
water in Beaker 3.3 (M&P Subassembly-3).
HEX- FFFF
("FFFF" indicates no digital activity.)
OPERATING PROCEDURE 17.11
PASSAGE OF WATER THROUGH TEST CORE
17.11.1 If nine cores are used, then complete steps 17.11.2 through 17.11.4.
If six cores are used, then complete steps 17.11.3 and 17.11.4. If three
cores are used, then complete step 17.11.4.
17.11.2 Open discharge-tube valves on M&P Subassembly 1 (valves 44, 45, and 46).
17.11.3 Open discharge-tube valves on M&P Subassembly 2 (valves 53, 55, and 58).
17.11.4 Open discharge-tube valves on M&P Subassembly 3 (valves 63, 64, and 66).
17.11.5 Monitor water levels in beakers. When water level reaches a minimum of
30 ml. close discharge-tube valve. (Note: this applies to all cores being
tested.)
17.11.6 Check discharge-tube tip for hanging drip. If hanging drip is present, remove
it by using a cotton swab. Discharge-tube tip is surrounded by photocell.
If hanging drip is allowed to remain, computer will continue to record data.
17.11.7 Remove beaker from beneath discharge-tube. Temporarily store beaker
between Subassembly and back wall.
17.11.8 When last discharge-tube valve has been shut off, go to Operating
Procedure 17.12.
OPERATING PROCEDURE 17.12
SHUT-DOWN PROCEDURE FOR SOFTWARE
17.12.1 Press key to exit program. "Files Closed" message will appear
on screen.
17.12.2 Depress any key.
17.12.3 Press key then press key. (This step should return to file.)
17.12.4 Press key to return to directory.
F62
-------
OPERATING PROCEDURE 17.13
RECORDING WET-WEIGHT OF 100-ML BEAKERS
17.13.1 Weights of 100-ml. beakers filled with discharged water should be recorded
in "Wet Weight" column, M&P Test Data Record. Beaker-numbers should
correspond to numbers of subassemblies and core-holders. Use format
shown below.
Dry Weight Wet Weight
(grams) (grams)
M&P Subassemblv 1
Beaker 1.1:
Beaker 1.2:
Beaker 1.3:
M&P Subassemblv 2
Beaker 2.1:
Beaker 2.2:
Beaker 2.3:
M&P Subassemblv 3
Beaker 3.1:
Beaker 3.2:
Beaker 3.3:
OPERATING PROCEDURE 17.14
SHUT-DOWN PROCEDURE, M&P SUBASSEMBLIES
17.14.1 Close nitrogen-regulating valve. (Valve is on regulator at nitrogen tanks-
valve closes with left-hand turn.) Note: When nitrogen-regulating valve'
is closed, nitrogen supply is closed to all subassemblies.
17.14.2 If nine cores are used, then complete steps 17.14.3 through 17.14 5 If six
cores are used, then complete steps 17.14.4 and 17.14.5. If three cores
are used, then complete step 17.14.5.
F63
-------
17.14.3 Shut-down M&P subassembly 1.
17.14.3.1 Close injection-port valve (valve 46).
17.14.3.2 Place container under drain-and-fill valve (valve 48).
17.14.3.3 Open bleed-port valve (valve 43).
17.14.3.4 Open drain-and-fill valve (valve 48).
17.14.3.5 Remove lower discharge-tube assembly with photocell from
core-holder 1.1.
17.14.3.6 Remove core-holder cap on core-holder 1.1.
17.14.3.7 Remove rubber core-holder sleeve from core-holder.
17.14.3.8 Remove core from rubber core-holder sleeve and store
in water bath.
17.14.3.9 Clean rubber core-holder sleeve.
17.14.3.10 Store photocell assembly in core-holder sleeve Store
core-holder sleeve and photocell at the back of counter-top.
17.14.3.11 Repeat steps 17.14.3.5 to 17.14.3.10 for remaininq
core-holders 1.2 and 1.3.
17.14.3.12 Close drain-and-fill valve (valve 48).
17.14.3.13 Clean and store glass beakers.
17.14.3.14 Clean counter-top.
17.14.4 Shut-down M&P subassembly 2.
17.14.4.1 Close injection-port valve (valve 56).
17.14.4.2 Place container under drain-and-fill valve (valve 59).
17.14.4.3 Open bleed-port valve (valve 52).
17.14.4.4 Open drain-and-fill valve (valve 59)
17.14.4.5 Remove lower discharge-tube assembly with photocell from
core-holder 2.1.
17.14.4.6 Remove core-holder cap on core-holder 2.1
17.14.4.7 Remove rubber core-holder sleeve from core-holder.
17.14.4.8 Remove core from rubber core-holder sleeve and store
F64
-------
in water bath.
17.14.4.9 Clean rubber core-holder sleeve.
17.14.4.10 Store photocell assembly in core-holder sleeve. Store
core-holder sleeve and photocell at the back of counter-top.
17.14.4.11 Repeat steps 17.14.4.5 to 17.14.4.10 for remaining
core-holders 2.2 and 2.3.
17.14.4.12 Close drain-and-fill valve (valve 59).
17.14.4.13 Clean and store glass beakers.
17.14.4.14 Clean counter-top.
17.14.5 Shut-down M&P subassembly 3.
17.14.5.1 Close injection-port valve (valve 65).
17.14.5.2 Place container under drain-and-fill valve (valve 67).
17.14.5.3 Open bleed-port valve (valve 62).
17.14.5.4 Open drain-and-fill valve (valve 67).
17.14.5.5 Remove lower discharge-tube assembly with photocell
from core-holder 3.1.
17.14.5.6 Remove core-holder cap on core-holder 3.1.
17.14.5.7 Remove rubber core-holder sleeve from core-holder.
17.14.5.8 Remove core from rubber core-holder sleeve and store
in water bath.
17.14.5.9 Clean rubber core-holder sleeve.
17.14.5.10 Store photocell assembly in core-holder sleeve. Store
core-holder sleeve and photocell at the back of counter-top.
17.14.5.11 Repeat steps 17.14.5.5 to 17.14.5.10 for remaining
core-holders 3.2 and 3.3.
17.14.5.12 Close drain-and-fill valve (valve 67).
17.14.5.13 Clean and store glass beakers.
17.14.5.14 Clean counter-top.
F65
-------
OPERATING PROCEDURE 17.15
SHUTTING DOWN COMPUTER
17.15.1 Press KEY.
17.15.2 Press "X" to exit.
17.15.3 Press .
17.15.4 Turn off monitor.
17.15.5 Turn off data-acquisition multiplex switch.
17.15.6 Turn off computer.
17.15.7 Turn off "AND" scale.
17.15.8 Turn off "OHAUS" scale.
F66
-------
APPENDIX G
SIMULATED LOWER WELLBORE DRAWINGS
Figure G1 shows how the wellhead slips had to be cut away in a sector, to
provide a conduit for the instrument lead-lines and the salt-water line. An adapter was
made for the salt-water line, so that the 1/2-in. and 1/4 in. tubing will pass through the
head, to connect to the 11/4 in. tubing below the slips.
Figure G2 shows how the casing was arranged by size to accommodate the
series of tests at different depths.
G1
-------
11-7/8'
5-1/2" Casing
1/2" S.S. Tubing
Supply Line
1/4" Bleed Line
Tubing Adaptor
8"
1-1/4" Injection Tubing
Figure G1 Wellhead configuration of tubing and casing.
G2
-------
1-1/4" Dia
Salt Water
Injection Tubing
N
176
I
171
53'
16;
81'
47
1.81'
47.
36
40.
.62'
,
22.19' I
I
58'
*».OV I
T"
61'
2.0'
-L-
30'
t
V 1 ,<•
TV 1
1 ^ \
I/I LJ "
Injection R. S 4 72-
._ 5-1/2" Casing
1 — 10-3/4" Casing
DPT = Validyne Differential Pressure Transducer
PT = Validyne Pressure Transducer
TC = Temperature Sensor
PT (ICS) = ICS Pressure Transducer
DSH = Diaphragm Seal Housing
- — . Location #6 (*PT PT (ICS) DSH TC)
30'
T 9
J I ^cation #4- (*PT DSH TC)
2*0' ' I 63'
{_ Location 03 (*PT DSH TC) 33'
l
13'
8"
y
j- Location #1. (DSH. TC)
N_ 3/4" Steel Plate
Figure G2 Location of tubing and instruments, Test No. 1.
G3
-------
APPENDIX H
MULTICORE-PERMEAMETER TESTS
MANUALLY COMPILED DATA AND COMPUTER-COMPILED DATA
H1
-------
Table H0.1 Code to identification of cores.
Tables in Core ID Artificial Sandstone
Appendix H Halliburton Mixture
Natural Sandstone/Comments on Artificial Sandstone
Table H1
Natural sandstone from the Barnsdall Sandstone.
Table H2
Natural sandstone from the Wellington Formation.
Table H3 7793 1.1,180,A 0.90 resin, 1.0 sand 20 % decrease in OK#1 sand; 80 % Increase in 12-20 frac sand.
1594.1:1,90 0 90 resin, 1.0 sand
1594:3:1,90 0 90 resin, 1.0 sand
1594:5:1.180 0.90 resin, 1.0 sand
0.90 resin, 1.0 sand
0.90 resin, 1.0 sand
0.90 resin, 1 0 sand
0.95 resin, 1.0 sand
0.95 resin. 1.0 sand
1694.3:0,0,A
1694.5:1,0,6
1289421.0.B
21294:1 1.0.A
21894:2:0.0,A
-------
Table HO 2 Code to identification of cores.
Tables In Core ID Artificial Sandstone
Appendix H Halliburton Mixture
Natural Sandstone/Comments on Artificial Sandstone
Table H4 7793 1 1.270.A 0.90 resin. 1.0 sand 20 % decrease in OK#1 sand; 60 % Increase In 12-20 frac sand
1594:2:1.180 0.90 resin. 1.0 sand
1594 3 1.270 0.90 resin. 1.0 sand
1694:5:1,90, A 0 90 resin. 1.0 sand
1694:5:1.180.A 0.90 resin. 1.0 sand
1694:3:1.180.A 0.90 resin, 1.0 sand
11894 3:1,90,A 0.90 resin. 1.0 sand
12594:3:1,90.8 0.90 resin. 1.0 sand
12894:1:1.270.8 0.90 resin. 1.0 sand
Table H5 10694:4:1,270.8 0.90 resin, 1.0 sand
021294:1:1,270,8 0 95 resin, 1.0 sand
021294:2:1.180.A 0.95 resin. 1.0 sand
031794:1 1.0.A 0 95 resin. 1.0 sand
032494:2:1,27d,A 0.95 resin, 1.0 sand
032494:2:1.90,8 1.00 resin. 1.0 sand
032494:2:1,180.8 1.00 resin, 1.0 sand
032494:2:1,90,0 1.00 resin, 1.0 sand
032494:2:1.180.0 1.00 resin. 1.0 sand
-------
Table HO 3 Code to identification of cores.
Tables in Core ID Artificial Sandstone Natural Sandstone/Comments on Artificial Sandstone
Appendix H Halliburton Mixture __
Table H6 021294 5 1,180,A 0 95 resin. 1.0 sand
021294.5.1,270,A 0.95 resin, 1.0 sand
021894-2:1.0.6 0.95 resin. 1.0 sand
021894.3.0.0.A 0.95 resin. 1.0 sand
021894 1 1,0,8 0.95 resin. 1 0 sand
030894:1:1.0,6 0.95 resin, 1.0 sand
0308941:1,90,8 0.95 resin, 1.0 sand
032494:1:1,0,0 0.95 resin, 1.0 sand
032494:1:1.180.0 0.95 resin. 1.0 sand
Table H7 7793.1:0,0,B 0 90 resin. 1.0 sand
010694:2:1.0.6 0.90 resin, 1.0 sand
010694:4:1,90,6 0.90 resin, 1.0 sand
021294:2:1,90.6 0.95 resin, 1.0 sand
021294-2:1.270,6 0.95 resin, 1.0 sand
021894:1:1.90,8 0.95 resin, 1.0 sand
021894:5:0,0. A 0.95 resin. 1.0 sand
032494:1:1.90.0 0.95 resin. 1.0 sand
032494:2:1.270.0 1.00 resin. 1.0 sand
-------
Table H0.4 Code to identification of cores
Tables in
Appendix H
Table H8
Table H9
Core
ID
021294 3 1.0.B
021294:3:1,90,6
021294 3 1.180.B
021894:3:1.180.8
021894:50.0.6
021894:51.90.6
030894:1:0.0,0
030894:1.1.270.0
031794:1:1,90,0
Artificial Sandstone Natural Sandstone/Comments on Artificial Sandstone
Halliburton Mixture
095
0.95
0.95
0.95
095
0.95
0.95
0.95
0.95
resin,
resin,
resin,
resin,
resin.
resin,
resin,
resin,
resin,
1.0
1.0
1.0
1.0
1.0
1.0
10
1 0
1.0
sand
sand
sand
sand
sand
sand
sand
sand
sand
Natural sandstone from the Pony Creek Shale.
Table H10
Natural sandstone from the Hughes Creek Shale.
-------
Table H0.5 Code to identification of cores.
Tables In Core ID Artificial Sandstone
Appendix H Halliburton Mixture
Natural Sandstone/Comments on Artificial Sandstone
IE
O>
Table H11 AR-2:1.270.P
AR-2:1.0,A
AR-2:0,0,B
AR-21.90.D
AR-2:0,0,0
AR-21.270.K
AR-21.90.M
AR-21.180.G
AR-2:1,180.1
0.95 resin, 1.0 sand Core plugs from the borehole core from the SIS reservoir.
0.95 resin, 1.0 sand
0 95 resin, 1.0 sand
0.95 resin, 1 0 sand
0.95 resin, 1 0 sand
0.95 resin, 1 0 sand
095 resin, 1.0 sand
0.95 resin, 1.0 sand
0.95 resin. 1.0 sand
-------
Table H1.1 M&P test data, natural sandstone. Barnsdall Formation, nominal 500 md permeability.
M&P TEST
PHASE
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
CORE ID
9 PER TEST
4 18 A
4.11.C
4.12.C
4.7.B
412.B
4.14.C
4.8 C
4.15.B
4.8.B
4.18.A
4.11.C
4.12.C
4.7.B
4.12.B
4.14.C
48.C
4.15.B
4.6.B
START END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATE/TIME DATE/TIME (fen of test) (psiq) (dea F) ffnsl
12/03/93
1444
15.15
15.81
17.19
17.85
18.45
19.55
20.37
20.87
12/04/93
47.01
47.62
48.44
49.32
49.92
50.20
51.08
51.95
52.72
12/03/93
56402
564.19
402.93
491.98
352.45
374.97
397.71
343.11
285.99
12/04/93
265.39
220.65
266.33
249.19
205.91
224.26
232.17
192.73
183.78
54958
549.04
387.12
474.77
334.60
356.52
378.16
322.74
265.12
218.38
173.03
217.89
199.87
155.99
174.06
181.09
140.78
131.06
AVERAGE
293
29.3
29.3
293
293
29.3
29.3
29.3
29.3
29.2
29.2
29.2
292
29.2
29.2
29.2
29.2
29.2
AVERAGE
68.6
68.6
68.6
68.5
68.5
68.5
69.3
693
69.3
69.9
69.9
69.9
69.5
69.5
69.5
70.2
70.2
702
AVERAGE
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
-------
Table H1.2 M&P test data, natural sandstone. Barnsdall Formation, nominal 500 md permeability
M&P TEST
PHASE
H20 PERM
H20 PERM
H2O PERM
H20 PERM
H2O PERM
H2O PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H2O WEIGHT
(am)
9 PER TEST
29.0
32.8
30.8
30.7
31.9
32.4
31.6
30.1
31.3
60.6
60.4
59.9
59.7
62.6
62.6
60.6
61.8
60.4
H2OVIS. M&P CORET" CORE "Ac"
(CP) ID (cm) (cm*cm) GAS LIQUID
9 PER TEST
1.018
1.018
1.018
1.019
1.019
1.019
1.007
1.007
1.007
0.998
0.998
0.998
1.004
1.004
1.004
0.994
0.994
0.994
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
31
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.485
3.472
3.487
3.465
3.477
3.482
3.485
3.482
3.470
3.485
3.472
3.487
3.465
3.477
3.482
3.485
3.482
3.470
9 PER TEST
5.327
5.337
5.324
5.327
5.337
5.341
5.324
5.344
5.331
5.327
5.337
5.324
5.327
5.337
5.341
5.324
5.344
5.331
PERMEABILITY
477.9
487.6
488.8
496.3
502.6
502.6
505.7
506.3
523.2
477.9
487.6
488.8
496.3
502.6
502.6
505.7
506.3
523.2
PERMEABILITY
17.62
19.84
2661
21.50
31 76
3029
27.63
30.70
38.82
91.00
114.00
91.00
98.00
132.00
119.00
110.00
143.00
150.00
I
CO
-------
Table H1 3 M&P test data, natural sandstone, Barnsdall Formation, nominal 500 md permeability.
M&P TEST
PHASE
H20 PERM
H20 PERM
H2O PERM
H20 PERM
H2O PERM
H2O PERM
H20 PERM
H2O PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
ANY APPROPRIATE COMMENT
Cores olaced from least permeable (1.1) to most permeable (3 3).
Test start and end times not recorded.
Test start and end times not recorded.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5 COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
X
CO
-------
Table H1 4 M&P test data, natural sandstone. Barnsdall Formation, nominal 500 md permeability.
M&P TEST CORE ID
I
_k
o
START
DATE/TIME
END RUNTIME PRESSURE TEMPERATURE FLOW RATE
PHASE
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MSI1
MSI1
MSI1
MSI1
MSI1
MSI1
MSI1
MSI1
MSI1
9 PER TEST
416.A
4.11.C
4.12.C
47.B
4.12.B
4.14 C
4.8.C
4.15.B
46.B
4.16.A
4.11.C
4.12.C
4.7.B
4.12.B
4.14.C
4.8.C
4.15.B
4.6.B
53.49
54.10
54.59
60.63
56.24
56.40
59.04
57.61
58.22
9100.00
9100.00
9100.00
9100.00
9100.00
9100.00
9100.00
9100.00
9100.00
9100.00
9100.00
9100.00
9100.00
9100.00
9100.00
9100.00
9100.00
9100.00
15907.00
15907.00
15907.00
15907.00
15907.00
15907.00
15907.00
15907.00
15907.00
11 VII Ul IC9IJ
9046.51
9045.90
9045.41
9039.37
9043.76
9043.60
9040.96
9042.39
9041.78
6807.00
6807.00
6807.00
6807.00
6807.00
6807.00
6807.00
6807.00
6807.00
luaiuj
AVERAGE
50.2
50.2
50.2
50.2
502
50.2
50.2
50.2
50.2
4.9
4.9
4.9
4.9
4.9
4.9
4.9
4.9
4.9
taeg rj
AVERAGE
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
(IDS)
AVERAGE
5 03
503
503
503
503
503
5 03
5 03
503
o
o
o
o
o
o
o
0
0
-------
Table H1 5 M&P lest data, natural sandstone. Barnsdall Formation, nominal 500 md permeability
M&P TEST
PHASE
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MSI1
MSI1
MSI1
MSI1
MSI1
MSI1
MSI1
MSI1
MSI1
H20 WEIGHT
(am)
9 PER TEST
6.7
6.0
6.6
6.7
5.6
4.8
5.7
6.0
4.2
0.8
1.2
1.3
0.4
0.8
0.9
1.1
0.9
0.8
H2OVIS. M&P CORE"L" CORE "Ac"
. (5Pl ID (cm) (cm*cm) GAS i mi nn
9 PER TEST
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.485
3.472
3.487
3.465
3.477
3.482
3.485
3.482
3.470
3.485
3.472
3.487
3.465
3.477
3.482
3.485
3.482
3.470
9 PER TEST
5.327
5.337
5.324
5.327
5.337
5.341
5.324
5.344
5.331
5.327
5.337
5.324
5.327
5.337
5.341
5.324
5.344
5.331
PERMEABILITY
477.9
487.6
488.8
496.3
502.6
502.6
505.7
506.3
523.2
477.9
487.6
488.8
496.3
502.6
502.6
505.7
506.3
523.2
PERMEABILITY
01300
0.1160
0.1280
0.1290
0.1080
0.0930
0.1110
0.1160
0.0810
0.2110
0.3150
03430
0.1050
02100
0.2370
0.2900
0.2370
02100
-------
Table H1 6 M&P test data, natural sandstone. Barnsdall Formation, nominal 500 md permeability.
M&P TEST
PHASE
MCB
MCB
MCB
MCB
MCB
MCB
T
_&
K)
MCB
MCB
MCB
MSI1
MSI1
MSI1
MSI1
MSI1
MSI1
MSI1
MSI1
MSI1
ANY APPROPRIATE COMMENT
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2 FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6 PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
-------
Table H1.7 M&P test data, natural sandstone, Barnsdall Formation, nominal 500 md permeability.
M&P TEST
CORE ID
START END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATE/TIME DATE/TIME (fen of lest) (pslg)
PHASE
MSI2
MSI2
MSI2
MSI2
MSI2
MSI2
MSI2
MSI2
MSI2
MSI3
MSI3
MSI3
MSI3
MSI3
MSI3
MSI3
MSI3
MSI3
9 PER TEST
4.16.A
4.11.C
4.12.C
4.7.B
4.12.B
4.14.C
4.8.C
4.15.B
4.6.B
4.16.A
4.11.C
4.12.C
4.7.B
4.12.B
4.14.C
4.8.C
4.15.B
4.6.B
15907.00
15907.00
15907.00
15907.00
15907.00
15907.00
15907.00
15907.00
15907.00
23418
23418
23418
23418
23418
23418
23418
23418
23418
22717.00
22717.00
22717.00
22717.00
22717.00
22717.00
22717.00
22717.00
22717.00
73723
73723
73723
73723
73723
73723
73723
73723
73723
6810.00
6810.00
6810.00
6810.00
6810.00
6810.00
6810.00
6810.00
6810.00
50305.00
50305.00
50305.00
50305.00
50305.00
50305.00
50305.00
50305.00
50305.00
AVERAGE
14.5
14.5
14.5
14.5
14.5
14.5
14.5
14.5
14.5
34.8
34.8
34.8
34.8
34.8
34.8
34.8
34.8
34.8
AVERAGE
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
75.8
758
75.8
75.8
75.8
75.8
75.8
75.8
AVERAGE
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
I
CO
-------
Table H1 8 M&P test data, natural sandstone, Barnsdall Formation, nominal 500 md permeability.
M&P TEST
PHASE
MSI2
MSI2
MSI2
MSI2
MSI2
MSI2
MSI2
MSI2
MSI2
MSI3
MSI3
MSI3
MSI3
MSI3
MSI3
MSI3
MSI3
MSI3
H20 WEIGHT
(am)
9 PER TEST
1.1
1.0
1.2
1.3
0.8
0.9
0.9
0.9
0.8
4.7
4.5
4.9
4.8
4.6
4.2
4.7
4.6
4.1
H2O VIS
(CD)
9 PER TEST
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0.915
0915
0.915
0.915
0.915
0.915
0.915
0.915
M&P CORE "L" CORE "Ac"
ID (cm) (cm'cm) GAS LIQUID
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.485
3.472
3.487
3.465
3.477
3.482
3.485
3.482
3.470
3.485
3.472
3.487
3.465
3.477
3.482
3.485
3.482
3.470
9 PER TEST
5.327
5.337
5.324
5.327
5.337
5.341
5.324
5.344
5.331
5.327
5.337
5.324
5.327
5.337
5.341
5.324
5.344
5.331
PERMEABILITY
477.9
487.6
488.8
496.3
502.6
502.6
505.7
506.3
523.2
477.9
487.6
4888
496.3
502.6
502.6
505.7
506.3
523.2
PERMEABILITY
0.0980
0.0890
01070
0.1150
0.0710
0.0800
0.0800
0.0800
0.0710
00240
0.0220
0.0025
0.0240
0.0230
0.0210
0.0240
0.0230
0.0210
-------
Table H1.9 M&P test data, natural sandstone, Barnsdall Formation, nominal 500 md permeability.
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
MSI2
MSI2
MSI2
MSI2
MSI2
MSI2
MSI2
MSI2
MSI2
MSI3
MSI3
MSI3
MSI3
MSI3
MSI3
MSI3
MSI3
MSI3
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4 BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
8. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
I
Ol
-------
Table H1.10 M&P test data, natural sandstone, Barnsdall Formation, nominal 500 md permeability.
M&P TEST
PHASE
INS1
INS1
INS1
INS1
INS1
INS1
INS1
INS1
INS1
INS2
INS2
INS2
INS2
INS2
INS2
INS2
INS2
INS2
CORE ID
9 PER TEST
4.16.A
4.11.C
4.12.C
4.7 B
4.12.B
4.14.C
4.8.C
4.15.B
4.6.B
4 18 A
4.11.C
4.12.C
47.B
4.12.B
4.14.C
4.8.C
4.15.B
4.6.B
START
DATE/TIME
84.00
64.00
84.00
64.00
64.00
64.00
64.00
64.00
64.00
16260
16260
16260
16260
16260
16260
16260
16280
16260
END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATE/TIME (fen of test) tosia) fden n ttnc\
15560.00
1556000
15560.00
15580.00
15560.00
15560.00
15560.00
15560.00
15560.00
30660
30660
30660
30860
30660
30660
30660
30660
30660
15496.00
15496.00
15496.00
15496.00
15496.00
15496.00
15496.00
15498.00
15496.00
1440000
14400.00
14400.00
14400.00
14400.00
14400.00
14400.00
14400.00
14400.00
AVERAGE
14.4
14.4
14.4
14.4
14.4
14.4
14.4
14.4
14.4
35
35
35
35
35
35
35
35
35
AVERAGE
73.9
73.9
73.9
73.9
73.9
73.9
73.9
739
73.9
73.5
73.5
73.5
73.5
73.5
73.5
73.5
73.5
73.5
AVERAGE
0
0
0
0
0
0
0
0
0
0
0
0
o
0
0
0
0
0
I
0>
-------
Table H1.11 M&P test data, natural sandstone, Barnsdall Formation, nominal 500 md permeability.
H2O WEIGHT H2OVIS. M&P CORE "L" CORE "Ac"
M&P TEST (am) (cp) ID (cm) (cm'cm) GAS LIQUID
PHASE
INS1
INS1
INS1
INS1
INS1
INS1
INS1
INS1
INS1
INS2
INS2
INS2
INS2
INS2
INS2
INS2
INS2
INS2
9 PER TEST
1 2
1.3
1.2
1.2
1.1
1.0
1.2
1.3
0.9
1.3
1.1
1.5
1.4
1.0
1.2
1.2
1.3
1.1
9 PER TEST
0945
0.945
0.945
0.945
0.945
0.945
0.945
0.945
0.945
0.947
0.947
0.947
0.947
0.947
0.947
0.947
0.947
0.947
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.485
3.472
3.487
3.465
3.477
3.482
3.485
3.482
3.470
3.485
3.472
3.487
3.465
3.477
3.482
3.485
3.482
3.470
9 PER TEST
5.327
5.337
5.324
5.327
5.337
5.341
5.324
5.344
5.331
5.327
5.337
5.324
5.327
5.337
5.341
5.324
5.344
5.331
PERMEABILITY
477.9
487.6
488.8
496.3
502.6
502.6
505.7
506.3
523.2
477.9
487.6
488.8
496.3
502.6
502.6
505.7
506.3
S23.2
PERMEABILITY
0.0490
0.0530
00490
00490
00450
00410
0.0490
00530
0.0360
0.0230
0.0200
00270
0.0250
0.0180
00220
0.0220
0.0230
00200
-------
Table H1.12 M&P test data, natural sandstone. Barnsdall Formation, nominal 500 md permeability
M&P TEST
PHASE
INS1
INS1
INS1
INS1
INS1
INS1
INS1
INS1
INS1
INS2
INS2
INS2
INS2
INS2
INS2
INS2
INS2
INS2
ANY APPROPRIATE COMMENT
14.7 psi target pressure.
35 psl target pressure.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2 FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4 BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
I
_*
03
-------
Table H1.13 M&P test data, natural sandstone, Barnsdall Formation, nominal 500 md permeability.
M&P TEST
CORE ID
START END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATE/TIME DATE/TIME (fen of test)
PHASE
INS3
INS3
INS3
INS3
INS3
INS3
INS3
INS3
INS3
9 PER TEST
4.16A
4.11.C
4.12.C
47.B
4.12.B
4.14.C
4.8.C
4.15.B
4.6.B
550.00
550.00
550.00
550.00
550.00
550.00
550.00
550.00
550.00
41950.00
41950.00
41950.00
41950.00
41950.00
41950.00
41950.00
41950.00
41950.00
41400.00
41400.00
41400.00
41400.00
41400.00
41400.00
41400.00
41400.00
41400.00
AVERAGE
498
49.8
49.8
49.8
498
498
49.8
49.8
49.8
AVERAGE
66.3
66.3
66.3
66.3
663
66.3
66.3
66.3
66.3
AVERAGE
0
0
0
0
0
0
0
0
0
I
<0
-------
Table H1 14 M&P test data, natural sandstone, Barnsdall Formation, nominal 500 md permeability.
H20 WEIGHT H2OVIS M&P CORET" CORE "Ac"
M&P TEST (am) (cp) ID (cm) (cm'cm) GAS LIQUID
PHASE
INS3
INS3
INS3
INS3
INS3
INS3
INS3
INS3
INS3
9 PER TEST
3.1
3.5
90.7
3.9
3.2
43.8
8.1
3.3
80
9 PER TEST
1.053
1.053
1.053
1.053
1.053
1.053
1.053
1.053
1.053
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.485
3.472
3.487
3.465
3.477
3.482
3.485
3.482
3.470
9 PER TEST
5.327
5.337
5.324
5.327
5.337
5.341
5.324
5.344
5.331
PERMEABILITY
477.9
487.6
488.8
496.3
502.6
502.6
505.7
506.3
523.2
PERMEABILITY
0.0150
0.0170
0.4460
0.0190
0.0160
0.2140
00400
0.0160
00390
I
N)
O
-------
Table H1.15 M&P lest data, natural sandstone. Barnsdall Formation, nominal 500 md permeability
M&P TEST
PHASE
INS3
INS3
INS3
INS3
INS3
INS3
INS3
INS3
INS3
ANY APPROPRIATE COMMENT
50 psl target pressure.
EXAMPLE COMMENTS
1 SENSOR PROBLEMS
2 FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5 COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
-------
Table H2 1 M&P test data, natural sandstone. Wellington Formation, nominal 350 md permeability.
M&P TEST
CORE ID
START END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATE/TIME DATE/TIME (fen of test) (pslg) (degF) (fps)
PHASE
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
9 PER TEST
T4:3
T52
T5:3
T3:2
T4:2
T5:5
T5:4
T4:4
T4:5
T4.3
T5.2
T5:3
T3:2
T4.2
T5:5
T5:4
T4:4
T4:5
03/07/94 16.38
60.08
63.60
66.45
69.59
72.22
75.08
77.44
78.81
80.57
03/08/94 13:48
70.63
103.91
96.99
5.82
69.86
734.40
101.88
112.70
131.76
03/07/94 16:52
540.08
851.89
548.59
852.66
537.44
490.92
530.19
505.36
475.10
03/09/94 14:16
63058.31
62855.69
63056.11
62975.20
62898.53
63014.64
63036.99
62880.07
63033.53
480.00
788.29
482.14
783.07
465.22
415.84
452.75
426.55
394.53
62987.68
82751.78
62959.12
62969.38
62828.67
62280.24
62935.11
82767.37
62901.77
AVERAGE
29.1
29.1
29.1
29.1
29.1
29.1
29.1
29.1
29.1
192.7
192.7
192.7
192.7
192.7
192.7
192.7
192.7
192.7
AVERAGE
71.5
71.5
71.5
71.3
71.3
71.3
70.9
70.9
70.9
74.9
74.9
74.9
74.9
74.9
74.9
74.9
74.9
74.9
AVERAGE
0
0
0
0
0
0
0
0
0
5.03
503
5.03
5.03
5.03
5.03
5.03
5.03
5.03
-------
Table H2 2 M&P test data, natural sandstone. Wellington Formation, nominal 350 md permeability.
H2O WEIGHT H2O VIS. M&P CORE "L" CORE "Ac"
MAP TEST tarn) (CD) ID (cm) (cm'cm)
PHASE
H2O PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
9 PER TEST
293.9
288.3
295.4
294.2
297.4
291.6
295.4
289.8
296.4
20.2
17.2
17.7
16.5
13.6
15.8
17
18.1
13.6
9 PER TEST
0.975
0.975
0.975
0.978
0978
0.978
0.983
0.983
0.983
0.927
0.927
0.927
0.927
0.927
0.927
0.927
0.927
0.927
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.480
3.482
3.482
3.482
3.482
3.480
3.482
3.482
3.482
3.480
3.482
3.482
3.482
3.482
3.480
3.482
3.482
3.482
9 PER TEST
5.237
5241
5.234
5.237
5.268
5.288
5.272
5.213
5.213
5.237
5.241
5.234
5.237
5.268
5.286
5.272
5.213
5.213
GAS
PERMEABILITY
337.6
337.9
338.4
354.5
342.1
354.3
355.4
379.0
398.9
337.6
337.9
338.4
3545
342.1
354.3
355.4
379.0
398.9
LIQUID
PERMEABILITY
200.34
119.66
200.73
123.38
208.71
227.99
214.11
225.48
24933
0.0151
0.0129
00132
00123
0.0101
0.0118
0.0126
0.0136
0.0102
N)
OJ
-------
Table H2.3 M&P test data, natural sandstone, Wellington Formation, nominal 350 md permeability.
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
H20 PERM
H20 PERM
H2O PERM
H20 PERM
H20 PERM
H2O PERM
H20 PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
Drip tubes shut off when volume of beakers approx. = 300 ml.
EXAMPLE COMMENTS .
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
-------
Table H2 4 M&P test data, natural sandstone, Wellington Formation, nominal 350 md permeability
START END RUN TIME
MAPTFST CORE ID DATE/TIME DATE/TIME (fcnoftest)
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
9 PER TEST
T4:3
T5:2
T5.3
T3.2
T4:2
T5:5
T5:4
T44
T4:5
03/09/94 18.44*
1101.31
1129.54
1006.34
978.02
793.06
1251.31
1040.61
815.69
961.85
03/21/94 08.32"
106704.65
106390.00
106375.20
106475.98
106496.78
106383.69
106581.98
108704.94
108578.58
105603.34
105280.48
105388.86
105499.98
105703.72
105132.38
105541.37
105889.25
105618.71
PRESSURE
(DSia)
AVERAGE
34.7
34.7
34.7
34.7
34.7
34.7
34.7
34.7
34.7
TEMPERATURE
(deg F)
AVERAGE
70.2
70.2
70.2
70.3
70.3
70.3
69.9
69.9
69.9
FLOW RATE
(fps)
AVERAGE
0
0
0
0
0
0
0
0
0
to
-------
Table H2 5 M&P test data, natural sandstone, Wellington Formation, nominal 350 md permeability.
H2O WEIGHT H2O VIS M&P CORE "L" CORE "Ac"
M&P TEST (am) (cp) ID (cm) (crrTcm) GAS LIQUID
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
9 PER TEST
88.1
99.8
224.5
27.7
23.7
229.8
39.9
93.9
357.6
9 PER TEST
0994
0.994
0.994
0.992
0.992
0.992
0.998
0.998
0.998
•
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3480
3.482
3.482
3.482
3.482
3.480
3.482
3.482
3.482
9 PER TEST
5.237
5.241
5234
5.237
5.268
5.286
5.272
5.213
5.213
PERMEABILITY
337.6
337.9
338.4
354.5
342.1
354.3
355.4
379.0
398.9
PERMEABILITY
0.2334
0.2652
0.5967
0.0734
0.0623
06048
0.1056
0.2505
0.9563
I
N>
CD
-------
Table H2 8 M&P test data, natural sandstone. Wellington Formation, nominal 350 md permeability
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
*Time computer program started.
INS 03/09/94: 21:29. Comp time 17125. Pressure increased
to 35 psi.
"Dale and time of last beaker wet weight taken; no other notes of
end time available.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4 BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
8. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
to
-------
Table H3.1 M&P test data, artificial sandstone, nominal 2000 md permeability
M&P TEST
CORE ID
START
DATE/TIME
END
DATE/TIME
RUNTIME PRESSURE TEMPERATURE FLOW RATE
PHASE
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
9 PER TEST
7793:1: 1.1 80. A
1694:5:1.0.6
1594:1:1.90
1694:3:O.O.A
21294:1 :1.0.A
12894.2:1.0.6
1594:5:1.180
21894:2:O.O.A
1594:3:1.90
7793. 1:1. 180. A
1694:5:1. 0.B
1594:1:1.90
1694:3:0,O.A
21294:1:1.0.A
12894:2:1.0.6
1594:5:1.180
21894:2:0,0,A
1594:3:1.90
04/27/94 13:31
53.16
53.71
54.26
55.25
56.13
56.95
58.05
58.77
59.31
04/28/94 14:40
81.39
84.91
83.87
85.07
90.18
87.49
88.75
90.07
91.23
04/27/94
115.01
83.92
86.17
111.82
110.89
112.81
114.62
115.39
90.40
04/28/94 16:23
6225.85
6204.27
6200.15
6208.83
6178.95
6187.35
6162.20
6191.14
6223.82
61.85
30.21
31.91
56.57
54.76
55.86
58.57
56.62
31.09
6144.46
6119.36
6116.28
6123.76
6088.77
6099.86
6073.45
6101.07
6132.59
| \WW
AVERAGE
28.6
28.6
28.6
28.6
28.6
28.6
26.6
28.6
28.6
50.7
50.7
50.7
50.7
50.7
50.7
50.7
50.7
50.7
. ^uc» r'
AVERAGE
70
70
70
69.8
69.8
69.8
69.3
69.3
69.3
84.9
84.9
84.9
84.9
84.9
84.9
84.9
84.9
84.9
. UP*)
AVERAGE
0
0
0
0
0
0
0
0
0
503
503
503
503
5.03
5.03
5.03
5.03
503
N)
00
-------
Table H3 2 M&P test data, artificial sandstone, nominal 2000 md permeability
M&P TEST
PHASE
H20 PERM
H20 PERM
H2O PERM
H20 PERM
H2O PERM
H2O PERM
H2O PERM
H20 PERM
H2O PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
H2O WEIGHT
(am)
9 PER TEST
191 7
190.1
208.2
1920
207.8
202.0
190.4
183.6
192.4
60
6.2
6.6
8.2
6.6
6.5
7.9
7.3
8.2
H20 VIS.
(CD)
9 PER TEST
0.997
0.997
0.997
1.000
1.000
1.000
1.007
1.007
1.007
0.804
0.804
0.804
0.804
0.804
0.804
0.804
0.804
0.804
M&P CORE "L" CORE "Ac"
ID (cm) (cm*cm) GAS I IQUin
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.541
3.500
3.500
3.498
3.493
3.482
3.495
3.498
3.498
3.541
3.500
3.500
3.498
3.493
3.482
3.495
3.498
3.498
9 PER TEST
5.31
5.344
5.355
5.348
5.355
5.365
5.344
5.348
5.341
5.31
5.344
5.355
5.348
5.355
5.365
5.344
5.348
5.341
PERMEABILITY
2065.1
2062.2
2054.7
1997.7
1995.6
1977.5
1971.3
1958.1
1938.7
2065.1
2062.2
2054.7
1997.7
1995.6
1977.5
1971.3
1958.1
19367
PERMEABILITY
1058.70
2111.23
2184.57
1140.42
1271.55
1205.94
1139.35
1097.66
2097.58
01518
0.1547
0.1644
0.2042
0.1648
0.1612
0.1983
0.1824
0.2041
N)
-------
Table H3.3 M&P test data, artificial sandstone, nominal 2000 md permeability.
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
H20 PERM
H20 PERM
H20 PERM
H2O PERM
H2O PERM
H2O PERM
H20 PERM
H2O PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
50 psl (file 42894mcb)
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4 BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
8. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
I
W
O
-------
Table H3 4 M&P test data, artificial sandstone, nominal 2000 md permeability.
M&P TEST
CORE ID
START
DATE/TIME
END
DATE/TIME
RUNTIME PRESSURE TEMPERATURE FLOW RATE
PHASE
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
9 PER TEST
7793:1 :1.180.A
1694:5:1.0.8
1594:1:1.90
1894:3:O.O.A
21294:1:1.0.A
12894.2:1.0.8
1594.5:1.180
21894:2:O.O.A
1594:3:1.90
7793: 1:1. 180. A
1694.5:1. 0.B
1594:1:1.90
1694.3:O.O.A
21294:1:1.0.A
12894:2:1.0.6
1594:5.1.180
21894.2:O.O.A
1594:3:1.90
04/28/94 16:23
56.46
57.01
63.21
5833
58.88
66.84
60.03
59.31
58.55
04/29/94 08:15
43.17
53.82
47.78
51.90
56.07
72.50
62.12
49.98
51.13
04/28/94 07:21
3564.11
3339.74
3529.73
3530.39
3537.47
3503.97
3543.79
3611.95
3609.86
04/29/94
20516.59
20517.58
20518.46
20512.74
20516.31
20517.19
20520.93
20521.88
20353.13
3507.65
3282.73
3466.52
3472.06
3478.59
3437.13
3483.76
3552.64
3551.31
20473.42
20463.76
20470.68
20460.84
20460.24
20444.69
20458.81
20471.88
20302.00
AVERAGE
90.7
90.7
90.7
907
90.7
90.7
90.7
90.7
90.7
29.3
29.3
29.3
29.3
29.3
29.3
29.3
29.3
29.3
. **•"« • *
AVERAGE
91.4
91.4
91.4
91 4
91.4
91.4
914
91.4
91.4
67.2
67.2
672
67.2
67.2
67.2
67.2
67.2
67.2
vv°i
AVERAGE
5.03
5.03
5.03
503
5.03
5.03
5.03
5.03
5.03
503
503
5.03
5.03
503
5.03
503
5.03
5.03
I
w
-------
Table H3 5 M&P test data, artificial sandstone, nominal 2000 md permeability.
I
W
M&P TEST
PHASE
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
H20 WEIGHT
(gm)
9 PER TEST
3.3
3.9
4.3
4.4
3.8
4.1
4.5
4.5
5.8
3.0
2.1
1.5
2.4
2.5
2.2
2.4
2.3
2.4
H2O VIS.
(CD)
9 PER TEST
0.736
0.738
0.738
0.738
0.738
0.738
0.736
0.738
0.738
1.039
1.039
1.039
1.039
1.039
1.039
1.039
1.039
1.039
M&P
ID
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
CORE "L"
(cm)
9 PER TEST
3.541
3.500
3.500
3498
3.493
3.482
3.495
3.498
3.498
3.541
3.500
3.500
3.498
3.493
3.482
3.495
3.498
3.498
CORE "Ac"
(cm*cm)
9 PER TEST
5.31
5.344
5.355
5.348
5.355
5.365
5.344
5.348
5.341
531
5.344
5.355
5.348
5.355
5.365
5.344
5.348
5.341
GAS
PERMEABILITY
2085.1
2062.2
2054.7
1997.7
19956
1977.5
1971.3
1958.1
1938.7
2065 1
2082.2
20547
1997.7
1995.6
1977.5
1971.3
1958.1
1938.7
LIQUID
PERMEABILITY
0074R
0 0928
0 0987
OOQflfl
00850
0 0923
0 1007
0 0988
0 1275
005O9
00350
00250
0 0400
00415
0 0364
00400
00383
0.0404
-------
Table H3 6 M&P test data, artificial sandstone, nominal 2000 md permeability.
M&P TEST
PHASE
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
ANY APPROPRIATE COMMENT
90 psl (file 42894mc2)
MCB 04/28/94: M&P shut down for the night.
14.7 psl (file 42894mc3)
35 psl
EXAMPLE COMMENTS
1 SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
I
W
W
-------
Table H3 7 M&P lest data, artificial sandstone, nominal 2000 md permeability.
M&P TEST
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
CORE ID
9 PER TEST
7793:1:1. 180.A
1694:5:1.0.6
1594:1:1.90
1694:3. 0.O.A
21294.1:1.0.A
12894:2:1.0.6
1594:5.1.180
21894:2:O.O.A
1594:3:1.90'
START
DATE/TIME
04/29/94 14:41
132.48
133.08
270.50
165.21
246.56
201.96
220.47
207.83
149.12
END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATEmME (fen of test) tosla) (deaR itn*\
04/30/94 09:10
17838.92
17855.39
17865.17
17779.82
17869.18
17836.94
17563.96
17860.28
16856.30
17706.44
17722.31
17594.67
17614.61
17622.62
17634.98
17343.49
17652.45
16707.18
AVERAGE
16.9
16.9
16.9
16.9
16.9
16.9
16.9
16.9
16.9
AVERAGE
63.4
63.4
63.4
626
62.6
626
61.8
61.8
61.8
AVERAGE
0
0
0
0
0
0
0
0
0
-------
Table H3 8 M&P test data, artificial sandstone, nominal 2000 md permeability.
M&P TEST
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
H20 WEIGHT
(am)
9 PER TEST
407
72.0
3940
34.7
139.8
403.2
91.7
70.9
187.0
H20 VIS.
(CD)
9 PER TEST
1.100
1.100
1.100
1.113
1.113
1.113
1.128
1.128
1.126
M&P CORE "L" CORE "Ac"
ID (cm) (cm'cm) GAS i mi nn
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.541
3.500
3.500
3.496
3.493
3.482
3.495
3.498
3.498
9 PER TEST
531
5.344
5.355
5.348
5.355
5.365
5.344
5.348
5.341
PERMEABILITY
2065.1
2062.2
2054.7
1997.7
1995.6
1977.5
1971.3
1958.1
1936.7
PERMEABILITY
1 4660
2.5451
13.9994
1.2471
50084
14.3657
33878
2.5734
7.1809
I
CO
en
-------
Table H3 9 M&P lest data, artificial sandstone, nominal 2000 md permeability.
M&P TEST
PHASE
INS
INS
.INS
INS
INS
INS
INS
INS
INS
ANY APPROPRIATE COMMENT
INS 04/29/94: Pressure Increased to 35 psi at 19:10.
INS 04/30/94: 400 ml beakers 1 .3 and 2.3 overflowed.
INS 04/30/94: Nitrogen bottle empty when test terminated.
INS 04/30/94: C drive full.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2 FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4 BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
-------
Table H4 1 M&P test data, artificial sandstone, nominal 2000 md permeability.
M&P TEST CORE ID
START
DATE/TIME
END
DATE/TIME
RUNTIME PRESSURE TEMPERATURE FLOW RATE
PHASE
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
9 PER TEST
1594.2:1.180
12594:3.1.90.6
1 694:5: 1.90.A
7793:1:1.270.A
1694:3.1. 180.A
12894:1:1.270.8
1594:3:1.270
11 894:3: 1.90.A
1694:5:1. 180.A
1594:2:1.180
12594:3:1.90.6
1694:5: 1.90.A
7793:1:1.270.A
1694:3. 1.180.A
12394:1:1.270.6
1594:3:1.270
11 894:3: 1.90.A
1694: 5: 1,1 80. A
05/03/94 15.57
52.34
53.05
53.55
5421
54.76
55.3
56.24
57.17
57.67
05/03/94 16:28
70.35
71.18
72.17
73.60
74.47
75.41
76.45
77.88
78.70
05/03/94
86.89
81.17
83.98
83.87
88.59
89.63
92.32
94.08
99.41
05/06/94 17:45
86400.00
86400.00
86400.00
86400.00
86400.00
86400.00
86400.00
172800.00
172800.00
34.55
28.12
30.43
29.66
33.83
34.33
36.08
36.91
41.74
86329.85
86328.82
86327.83
86326.40
66325.53
86324.59
86323.55
172722.12
172721.30
1MJIMJ
AVERAGE
28.7
28.7
28.7
28.7
28.7
28.7
28.7
28.7
28.7
45.4
45.4
45.4
454
45.4
45.4
45.4
45.4
45.4
. mc» ri
AVERAGE
68.1
68.1
681
67.4
67.4
67.4
68.2
68.2
68.2
75.1
75.1
75.1
75.1
75.1
75.1
75.1
751
75.1
. t'PSJ
AVERAGE
0
0
o
0
o
0
0
0
0
5.03
5.03
503
503
5.03
5.03
5.03
5.03
5.03
I
W
-------
Table H4 2 M&P lest data, artificial sandstone, nominal 2000 md permeability.
M&P TEST
PHASE
H2O PERM
H20 PERM
H20 PERM
H2O PERM
H20 PERM
H2O PERM
H20 PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
H20 WEIGHT
(am)
9 PER TEST
194.1
187.4
189.5
195.1
223.1
194.9
193.9
227.8
193
221.9
207.5
178.4
117.8
172.4
178.4
227.5
212.5
235.9
H2O VIS.
(CD)
9 PER TEST
1.025
1.025
1025
1036
1.036
1.038
1.024
1.024
1.024
0.925
0.925
0.925
0.925
0.925
0.925
0925
0.925
0.925
M&P CORE "L" CORE "Ac"
ID (cm) (cm'cm) GAS iininn
9 PER TEST
1.1
1.2
1.3
2.1
2.2
23
3.1
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.493
3.498
3.498
3.513
3.498
3.495
3.495
3.500
3.500
3.493
3.498
3498
3.513
3.498
3.495
3.495
3.500
3.500
9 PER TEST
5.334
5.355
5.248
5.306
5.344
5.365
5.341
5.348
5.344
5.334
5.355
5.248
5.308
5.344
5.385
5.341
5.348
5.344
PERMEABILITY
2064.3
2062.4
2051.0
2000.1
1995.4
1977.8
1971.2
1959.8
1936.7
2064.3
20624
2051.0
2000.1
1995.4
1977.8
1971.2
1959.8
1936.7
PERMEABILITY
1931.38
2285.43
2179.15
231048
2289.95
1962.22
1843.75
2117.69
1587.75
0.503914
0.470052
0.412376
0 270499
0.391358
0.398586
0.516365
0.241089
0 267839
(A)
00
-------
Table H4 3 MAP test data, artificial sandstone, nominal 2000 md permeability.
M&P TEST
PHASE
H20 PERM
H2O PERM
H20 PERM
H2O PERM
H2O PERM
H20 PERM
H20 PERM
H2O PERM
H2O PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
ANY APPROPRIATE COMMENT
H2O PERM 05/03/94: 2.1 dripped much slower than all others.
Water in beaker 2.1 was clear, but all others had a rust-yellow tint.
MCB 05/04/94: Approx. 08:30: Photo cell 3.3 showina activity wh
there was no drip. The problem was corrected by adiustlna wires
MCB 05/04/94 17:38: Photo cell 3.3 showina activity with no drio
MCB 05/05/94: 08:30: Mixed more mud due to pump leakaae.
MCB 05/05/94: 09:58: Mud diverted back to mcp.
MCB 05/05/94: 1 1 :00: Comp. time=66620: disk full.
MCB 05/06/94: 13:30: Switched from 250 ml beakers to 100mL
beakers.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4 BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
I
w
(O
-------
Table H4 4 M&P test data, artificial sandstone, nominal 2000 md permeability.
M&P TEST CORE ID
START END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATE/TIME DATE/TIME (fen of lest)
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
9 PER TEST
1594:2:1.180
12594:3:1.90.6
1694:5.1. 90.A
7793.1:1.270.A
1694:3.1. 180.A
12394:1:1.270.6
1594.3.1.270
11 894:3:1. 90.A
1694:5: 1.180.A
05/06/94 18:48
77.88
78.48
79.14
79.97
80.63
81.12
82.00
82.17
83.43
05/07/94 07:43
45682.68
46539.02
46349.48
46643.82
46345.08
46592 91
46179.70
46323.44
43940.17
45604.80
46460.54
46270.34
46563.85
46264.45
46511.79
46097.70
46241.27
43856.74
AVERAGE
49.3
49.3
49.3
49.3
49.3
49.3
49.3
49.3
49.3
AVERAGE
73.1
73.1
73.1
73.5
73.5
73.5
73.2
73.2
73.2
AVERAGE
0
0
0
0
0
0
0
0
0
Jt
o
-------
Table H4.5 M&P test data, artificial sandstone, nominal 2000 md permeability.
H20 WEIGHT H2O VIS. M&P CORE "L" CORE "Ac"
M&P TEST (gm) (CD) ID (cm) (cm'cm) GAS LIQUID
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
9 PER TEST
404.3
79.8
27.9
220.4
303.2
256
418.2
40.1
48.1
9 PER TEST
0.952
0.952
0.952
0.947
0.947
0.947
0.951
0.951
0.951
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.493
3.498
3.498
3.513
3.498
3.495
3.495
3.500
3.500
9 PER TEST
5334
5.355
5.248
5.306
5.344
5.365
5.341
5.348
5.344
PERMEABILITY
2064.3
2062.4
2051.0
2000.1
1995.4
19778
1971.2
1959.8
19367
PERMEABILITY
1.6480
0.3177
0.1141
0.8845
1.2106
1.0120
16830
0.1609
02036
-------
Table H4.6 M&P test data, artificial sandstone, nominal 2000 md permeability.
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
INS 05/07/94. 07:43: Breakthrough on 1.1 and 3.1;
subassembly #2 also out of water.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3 BEAKER OVERFLOW
4 BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6 PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
Jt
N)
-------
Table H5.1 M&P test data, artificial sandstone, nominal 1500 md permeability.
START END RUNTIME PRESSURE
M&P TEST CORE ID DATE/TIME DATE/TIME (fen of test) (psifl)
PHASE
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
9 PER TEST
21294.2:1. 180.A
10694:4:1.270.8
032494.2:1.90.0
032494:2:1.90.6
032494:2:1.180.6
032494 2: 1.270. A
021294:1:1.270.6
032494:2:1.180,0
031704:1:1,0,A
21 294:2:1. 180.A
10694:4:1.270.6
032494:2:1. 90.C
032494:2:1.90.6
032494:2:1.180.6
032494:2: 1.270.A
021294:1:1.270.6
032494:2:1,180,0
031 794:1 :1.0.A
05/11/94 15:43
91.34
92.11
93.04
93.92
94.69
95.35
96.39
96.99
97.49
05/12 11.27
85.40
86.17
86.72
87.60
88.15
88.59
89.36
89.91
90.35
05/11/94 15.49
177.84
175.70
174.05
154.50
138.90
136.43
143.13
154.83
180.86
05/13 1600*
104513.37
104560.02
104576.16
104568.31
104502.99
104604.28
104541.64
104591.60
104566.55
86.50
83.59
81.01
60.58
44.21
41.08
46.74
57.84
83.37
104427.97
104473.85
104489.44
104500.71
104414.84
104515.69
104452.28
104501.69
104476.20
AVERAGE
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
28.6
51.4
51.4
51.4
51.4
51.4
51.4
51.4
51.4
51.4
TEMPERATURE
(deaF)
AVERAGE
68.2
68.2
68.2
69.2
69.2
69.2
69.5
69.5
69.5
85.4
85.4
854
85.4
85.4
85.4
85.4
85.4
85.4
FLOW RATE
(fDS)
AVERAGE
0
0
0
0
0
0
0
0
0
1.81
1.81
1.81
1.81
1.81
1.81
1.81
1.81
1 81
-------
Table H5 2 M&P test data, artificial sandstone, nominal 1500 md permeability.
M&P TEST
PHASE
H20 PERM
H20 PERM
H2O PERM
H2O PERM
H20 PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
H20 WEIGHT
(qm)
9 PER TEST
191.8
21.4
201.4
195.2
196.9
196.5
199.6
190.0
195.8
87.8
81.7
92.3
26.7
27.6
41.2
26.8
42.4
45.3
H2O VIS.
(CD)
9 PER TEST
1.02
1.02
1.02
1.01
1.01
1.01
1.00
1.00
1.00
0.798
0.798
0.798
0.798
0.798
0.798
0.798
0.798
0.798
M&P CORE "L" CORE "Ac"
ID (cm) (cm*cm) GAS I louin
9 PER TEST
1 1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3526
3.495
3.495
3.495
3.500
3.495
3.495
3.498
3.495
3.526
3.495
3.495
3.495
3.500
3.495
3.495
3.498
3.495
9 PER TEST
5.355
5.337
5.292
5.292
5.282
5.303
5.355
5.282
5.428
5.355
5.337
5.292
5.292
5.282
5.303
5.355
5.282
5.428
PERMEABILITY
1527.0
1518.7
1505.9
1504.1
1502.4
1499.3
1481.8
1480.4
1477.3
1527.0
1518.7
1505.9
1504.1
1502.4
1499.3
1481.8
1480.4
1477.3
PERMEABILITY
76802
88.20
863.83
1103.10
152983
1634.16
1438.36
1122.53
780.40
0.1264
0.1169
0.1332
0.0385
0.0400
0.0593
0.0382
00614
0.0638
-------
Table H5.3 M&P test data, artificial sandstone, nominal 1500 md permeability
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
H2O PERM
H20 PERM
H2O PERM
H20 PERM
H2O PERM
H20 PERM
H2O PERM
H2O PERM
H2O PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
H2O PERM 05/1 1/94: 15:49: ComD. time 390. 2.2 dripping
very slowly.
H2O PERM 05/11/94: Approx. 18:00: H2O perm run on
1.2 again, file name: m&pdata\51194H3O.
*Approx. End Time
MCB 05/12/94: 22:23: Photo cell 1.2 stuck on (cleaned).
MCB 05/13/94: 13:31: Photo cell 3.3 stuck on.
Photo cell cleaned at 13:34; comp. time 7630.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
8. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
•ft
01
-------
Table H5.4 M&P test data, artificial sandstone, nominal 1500 md permeability.
M&P TEST
CORE ID
START
DATE/TIME
END
DATE/TIME
RUNTIME PRESSURE TEMPERATURE FLOW RATE
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
9 PER TEST
21294:2.1. 160.A
10694:4.1. 270.B
032494:2:1.90.0
032494:2:1.90.6
032494:2:1.180.6
032494:2: 1.270.A
021294:1:1.270.8
032494:2:1.180.0
031794:1:1.0.A
05/13/94 16:57
22.29
23.50
24.55
26.14
27.07
28.94
30.20
31.08
31.91
05/16/94 16:53
258915.42
258911.56
257858.13
258841.48
258838.50
258856.19
258687.00
258934.00
258929.00
258893.13
258888.06
257833.58
258815.34
258811.43
258827.25
258656.80
258902.92
258897.09
AVERAGE
50.1
50.1
50.1
50.1
50.1
50.1
50.1
50.1
50.1
AVERAGE
74.1
74.1
74.1
74.6
74.6
746
739
73.9
73.9
i \'r**i
AVERAGE
0
0
0
0
0
0
0
0
0
*
tn
-------
Table H5 5 M&P test data, artificial sandstone, nominal 1500 md permeability.
H2O WEIGHT H2O VIS. M&P CORE "L" CORE "Ac"
M&P TEST (gm) (cp) ID (cm) (cm*cm) GAS LIQUID
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
9 PER TEST
195.2
176.6
270.5
66.9
57.3
88.2
45.2
68.6
84.2
9 PER TEST
0.938
0.938
0.938
0.931
0931
0.931
0.941
0.941
0.941
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.526
3.495
3.495
3.495
3.500
•3.495
3.495
3.498
3.495
9 PER TEST
5.355
5.337
5.292
5.292
5.282
5.303
5.355
5.282
5.428
PERMEABILITY
1527.0
1518.7
1505.9
1504.1
1502.4
1499.3
1481.8
1480.4
1477.3
PERMEABILITY
01367
0.1230
0.1908
0.0467
00401
0.0614
00315
0.0484
00578
-------
Table H5.6 M&P test data, artificial sandstone, nominal 1500 md permeability.
M&P TEST
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
ANY APPROPRIATE COMMENT
•
••»
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
.&.
oo
-------
Table H6 1 M&P test data, artificial sandstone, nominal 1000 md permeability.
4k.
-------
Table H6.2 M&P test data, artificial sandstone, nominal 1000 md permeability.
H20 WEIGHT H2O VIS. M&P CORET1 CORE "Ac"
M&P TEST (am) (cp) ID (cm) (cm*cm) GAS LIQUID
PHASE
H20 PERM
H2O PERM
H20 PERM
H20 PERM
H2O PERM
H2O PERM
H20 PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
9 PER TEST
201.3
195.4
196.6
198.5
194.2
199.5
201.4
198.5
204.0
59.2
171.2
138.4
203.6
224.4
158.6
161.1
172.2
130.0
9 PER TEST
1.082
1.082
1.082
1.090
1.090
1.090
1.101
1.101
1.101
0813
0.813
0.813
0.813
0.813
0.813
0.813
0.813
0.813
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.500
3.498
3.490
3.500
3.495
3.505
3.508
3.513
3.503
3.500
3.498
3.490
3.500
3.495
3.505
3.508
3.513
3.503
9 PER TEST
5.355
5.355
5.355
5.320
5.320
5.337
5.344
5.372
5.365
5.355
5.355
5.355
5.320
5.320
5.337
5.344
5.372
5.365
PERMEABILITY
1209.4
1018.6
1001.9
1000.6
999.2
1071.2
986.3
976.0
975.1
1209.4
1018.6
1001.9
1000.6
9992
1071.2
986.3
976.0
975.1
PERMEABILITY
981.13
742.06
877.70
1027.71
949.41
1214.40
1000.59
807.13
963.92
0.0930
0.2686
02167
0.3217
03544
0.2503
0.2539
0.2704
0.2038
I
01
o
-------
Table H6.3 M&P test data, artificial sandstone, nominal 1000 md permeability.
M&P TEST
PHASE
H20 PERM
H2O PERM
H2O PERM
H2O PERM
H20 PERM
H20 PERM
H20 PERM
H2O PERM
H2O PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
ANY APPROPRIATE COMMENT
H20PERM 05/18/94: Note nltroaen perm. 1.1: core mistakenlv
used in this M&P test.
<
H2O PERM 05/18/94: Note nitroaen Derm. 2.3: core mistakenlv
used in this M&P test.
MCB 05/19/94: 04:41: Comp. time 62500: Photo cell 3.3 stuck o
MCB 05/19/94: 04:58: Comp. time 83540: Photo cell 3.3 stuck o
MCB 05/19/94: 04:59: Photo cell 2.1 stuck on.
MCB 05/19/94: 08:15: Comp. time 681 20: Photo cell 3.3 stuck o
(Photocells were cleaned, correctina the problems.)
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5 COMPUTER MEMORY FILLED
8. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
I
01
-------
Table H6.4 M&P test data, artificial sandstone, nominal 1000 md permeability.
M&P TEST
CORE ID
START END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATE/TIME DATE/TIME (fen of test)
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
9 PER TEST
030894:2: 1.0.A
021894:2:1.0.6
021294:5:1,270,A
032494:1:1.0.0
032494:1:1. 180.D
030894:2:1. 90.A
021894:1:1.0.6
021 894:3:0.0. A
021294:5:1. 180.A
05/19/94 5:37
16.25
16.80
18.01 -
18.07
21.03
20.81
21.86
22.46
23.28
05/22/94 15:38"
210690.09
210334.52
210619.34
210635.88
210665.14
210513.95
210438.3
210677.92
210635.47
236174.00
236174.00
236174.00
236174.00
236174 00
236174.00
236174.00
236174.00
236174.00
AVERAGE
49.9
49.9
49.9
49.9
49.9
49.9
49.9
49.9
49.9
AVERAGE
76.3
78.3
78.3
78.3
763
76.3
78.3
76.3
76.3
1 vr~i
AVERAGE
0
0
0
0
0
0
0
0
0
I
en
K)
-------
Table H6 5 M&P test data, artificial sandstone, nominal 1000 md permeability
M&P TEST
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
H2O WEIGHT
(am)
9 PER TEST
139.5
182.7
181.2
197.5
237.4
182.6
322.7
198.2
155.6
H2O VIS.
(CD)
9 PER TEST
0.909
0.909
0.909
0909
0.909
0.909
0.909
0.909
0.909
M&P CORE "L" CORE "Ac"
ID (cm) (cm'cm) GAS iioinn
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.500
3.498
3.490
3.500
3.495
3.505
3.508
3.513
3.503
9 PER TEST
5355
5.355
5.355
5.320
5.320
5.337
5.344
5.372
5.365
PERMEABILITY
12094
1018.6
1001.9
1000.6
999.2
1071.2
986.3
976.0
975.1
PERMEABILITY
0 1034
0.1353
0.1339
0.1473
0.1768
0.1359
0.2401
0.1469
01151
I
Ol
W
-------
Table H6.6 M&P test data, artificial sandstone, nominal 1000 md permeability.
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
INS 05/22/94: "Disk full before 08:30. Program restarted without
saving data at 1 1 :30.
INS 05/19/94: Run time, average pressure, and average
temperature were calculated from hand data, due to a disk
failure, resulting in the loss of some computer data.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
-------
Table H7 1 M&P test data, artificial sandstone, nominal 1250 permeability
M&P TEST
CORE ID
START
DATEmME
END RUNTIME PRESSURE TEMPERATURE FLOW RATE
PHASE
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
9 PER TEST
021294.2:1.270.6
021294:2:1.90.8
010694:4.1.90.8
032494:2 1.270.C
070793:1.0.0.8
021894.5.0.0.A
021894:1:1.90.8
010694:2:1.0.8
032494:1:1.90.0
021294:2:1. 270.B
021294:2:1.90.6
010694:4 1.90.B
032494:2:1, 270.C
070793:1:0.0.6
021 894:5:0.0. A
021894:1:1.90.8
010694:2:1.0.8
032494:1:1.90.0
05/24/94
191.41
192.07
192.89
193.83
194.87
195.69
196.63
197.56
198.39
05/25/94 10:14
185.37
188.47
186.74
187.68
198.94
189.10
231.84
190.42
190.97
05/24/94
250.24
247.78
241.83
247.05
505.75
244.08
253.86
253.48
258.03
05/26/94 13:21
97785.16
97766.97
97739.47
97767.92
97766.48
97765.02
97761.29
97760.29
97757.99
58.83
55.69
48.94
53.22
310.88
48.39
57.23
55.92
59.64
97579.79
97580.50
97552.73
97580.24
97567.54
97575.92
97529.45
97569.87
97567.02
iMaim
AVERAGE
28.5
285
28.5
28.5
28.5
28.5
28.5
28.5
28.5
50.4
50.4
504
50.4
50.4
50.4
50.4
50.4
50.4
. i"e» r>
AVERAGE
69.6
69.6
69.6
71.1
71.1
71.1
71.6
71.6
71.6
83.9
83.9
83.9
83.9
83.9
83.9
83.9
83.9
83.9
(IPS)
AVERAGE
0
0
0
0
0
0
0
0
'o
1 78
1.78
1.78
1 78
1.78
1.78
1.78
1.78
1 78
01
-------
Table H7 2 M&P test data, artificial sandstone, nominal 1250 permeability.
M&P TEST
PHASE
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H2O PERM
H2O PERM
H20 PERM
H2O PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
H20 WEIGHT
(am)
9 PER TEST
192.2
189.7
200.2
193.6
196.0
189.0
201.0
190.5
199.3
218.8
214.5
185.7
105.2
47.7
190.4
64.3
83.1
132.1
H2O VIS.
(CD)
9 PER TEST
1.003
1.003
1.003
0.981
0.981
0.981
0.973
0.973
0.973
0.815
0.815
0.815
0.815
0.815
0.815
0.815
0.815
0.815
M&P
ID
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
31
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
CORE "L"
(cm)
9 PER TEST
3.493
3.505
3.493
3.495
3.515
3.498
3.490
3.495
3.487
3.493
3.505
3.493
3.495
3.515
3.498
3.490
3.495
3.487
CORE "Ac"
(cm*cm)
9 PER TEST
5.355
5.355
5.344
5.303
5.251
5.348
5.337
5.344
5.313
5.355
5.355
5.344
5.303
5.251
5.348
5.337
5.344
5.313
GAS
PERMEABILITY
1298.2
1286.8
1284.1
1264.8
1250.5
1240.5
1228.5
1207.0
1199.8
1298.2
1286.8
1284.1
1264.8
1250.5
1240.5
1228.5
1207.0
1199.8
LIQUID
PERMEABILITY
1101 82
115299
1382.45
121259
21347
1291.92
11 38 00
1118.58
1101.25
0.3478
0.3422
0.2640
0.1690
0.0778
0.3035
0.1025
0.1325
0.2113
-------
Table H7.3 M&P test data, artificial sandstone, nominal 1250 permeability.
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
H2O PERM
H2O PERM
H20 PERM
H2O PERM
H2O PERM
H20 PERM
H2O PERM
H2O PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
H2O PERM 05/24/94: Core 2.2 removed, turned upside down,
replaced In permeameter and re-tested; file name
m&pdata\52494h3o (core dripped slowly).
Note nitrogen perm 3.3; this core used in place of one mistakenly
used in earlier test.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5 COMPUTER MEMORY FILLED
6 PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
X
Ol
-------
Table H7.4 M&P test data, artificial sandstone, nominal 1250 permeability.
M&P TEST
CORE ID
START END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATE/TIME DATE/TIME (fen of test) (pslg) (deg F) (fps)
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
9 PER TEST
021294:2:1.270.6
021294:2.1.90.6
010894:4:1.90.6
032494:2:1.270.0
070793:1:0.0.6
021 894:5:0.0. A
021894.1:1.90.6
010694:2:1.0.6
032494:1:1.90.0
05/26/94 13.44
65.52
81.45
66.67
67.72
77.93
68.71
162.03
70.03
70.74
05/29/94 07:38"
45161144
278606.50
192379.75
278774.18
278818.91
278596.81
365197.16
278795.16
365223.13
451545.92
278525.05
192313.08
278706.44
278740.98
278528.10
365035.13
278725.13
365152.39
AVERAGE
50.1
50.1
50.1
50.1
50.1
50.1
50.1
50.1
501
AVERAGE
75.6
75.8
75.6
76
76
76
75.3
75.3
75.3
AVERAGE
0
0
0
0
0
0
0
0
0
I
01
00
-------
Table H7 5 M&P test data, artificial sandstone, nominal 1250 permeability.
M&P TEST
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
H20 WEIGHT H2O VIS. M&P CORE "L" CORE "Ac"
(am) (CD) ID (cm) (cm'cm) GAS LIQUID
9 PER TEST
492.2
348.3
503.1
225.9
208.9
334.0
197.2
218.0
245.7
9 PER TEST
0.918
0.918
0.918
0.913
0.913
0.913
0.922
0.922
0.922
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.493
3.505
3.493
3.495
3.515
3498
3.490
3.495
3.487
9 PER TEST
5.355
5.355
5.344
5.303
5.251
5.348
5.337
5.344
5.313
PERMEABILITY
1298.2
1286.8
1284.1
12648
1250.5
1240.5
1228.5
1207.0
1199.8
PERMEABILITY
0.1915
02205
0.4605
0.1431
01344
0.2100
00956
0.1384
0.1195
I
Ul
CO
-------
Table H7.6 M&P test data, artificial sandstone, nominal 1250 permeability.
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
"Disk full at some time before this time.
INS 05/27/94: 16:52: Comp. time 11360: Measured beaker wet
weights of subassembly #1 . Refilled subassembly #1 and put bac
on test at 16:58.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
I
o>
O
-------
Table H8.1 M&P test data, artificial sandstone, nominal 500 md permeability.
M&P TEST
PHASE
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
START END RUNTIME PRESSURE TEMPERATURE FLOW RATE
CORE ID DATEmME DATE/TIME (fen of test) (psig) (dea F) (fosl
9 PER TEST
030894:1:1.270.0
021894.5.0.0.8
031794.1:1.90.0
021294:3:1.0.6
021894.3:1.180.6
0212943:1.90.6
030894:1:0.0.0
021894.5:1.90.6
021294:3:1.180.6
030894:1:1.270.0
021894:5:0.0.6
031794:1:1.90.0
021294:3:1.0.6
021894:3:1.180.6
021294:3:1.90.6
030894:1:0.0.0
021894:5:1.90.8
021294:3:1,180.6
06/01/94 09:55
113.86
114.57
115.34
116.22
118.25
118.47
120.28
121 27
122.15
06/01/94 13:45
94.80
98.04
96.88
100.07
101.22
120.28
103.64
103.80
104.90
06/01/94 11.06
3334.69
4120.18
1790.02
1567.29
4138.74
251.50
1901.13
3335.13
3486.61
06/02/94 13:58
86982.15
87049.75
87055.87
86981.98
87066.52
87046.73
87081.88
87027.02
87096.30
3220.83
4005.61
1674.68
1451.07
4020.49
133.03
1780.85
3213.86
3364.46
86887.35
86951.71
86958.99
86881.91
86965.30
86926.45
86978.24
86923.22
86991.40
AVERAGE
29.1
29.1
29.1
29.1
29.1
29.1
29.1
29.1
29.1
50.7
50.7
50.7
50.7
50.7
507
50.7
50.7
50.7
AVERAGE
75.2
75.2
75.2
75.0
75.0
75.0
75.1
75.1
75.1
88.8
88.8
88.8
88.8
88.8
88.8
88.8
88.8
88.8
AVERAGE
0
0
0
0
0
0
0
0
0
1.76
1 76
1.76
1.76
1.76
1.76
1.76
1.76
1.76
o>
-------
Table H8.2 M&P test data, artificial sandstone, nominal 500 md permeability.
M&P TEST
PHASE
H20 PERM
H2O PERM
H2O PERM
H2O PERM
H20 PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
MCB
MOB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
H20 WEIGHT
(gm)
9 PER TEST
96.4
96.2
96.6
96.3
94.5
94.3
100.9
95.2
999
77.7
171.2
213.8
32.3
38.0
113.4
508
36.1
63.2
H2OVIS. M&P CORE"L" CORE "Ac"
(CD) ID (cm) (cm'cm) GAS LIQUID
9 PER TEST
0.923
0.923
0.923
0.926
0.926
0.926
0.925
0.925
0.925
0.762
0.782
0.762
0.762
0.762
0.762
0.762
0.762
0.762
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
1.1
1.2
1.3"
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.498
3.500
3.531
3.513
3.500
3.500
3.510
3.493
. 3.518
3.498
3.500
3.531
3.513
3.500
3.500
3.510
3.493
3.518
9 PER TEST
5.337
5.351
5.463
5.355
5.365
5.355
5.344
5.358
5.355
5.337
5.351
5.463
5.355
5.365
5.355
5.344
5.358
5.355
PERMEABILITY
535.8
532.8
531.3
528.9
509.8
506.7
496.3
490.6
468.8
535.8
532.8
531.3
528.9
509.8
508.7
496.3
490.6
468.8
PERMEABILITY
9.15
7.33
17.39
2037
7.17
21675
17.39
902
9.11
01295
02845
0.3511
0.0539
0.0630
0.1884
00848
0.0598
0.1054
O)
-------
Table H8 3 M&P test data, artificial sandstone, nominal 500 md permeability.
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
H20 PERM
H2O PERM
H20 PERM
H20 PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
Beakers filled to 100 ml_.
H2O PERM 06/01/94: Comp. time 4170: Photocell 3.3 stuck on.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2 FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4 BEAKER CHANGE DURING TEST
5 COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
o>
03
-------
Table K8 4 M&P test data, artificial sandstone, nominal 500 md permeability.
M&P TEST
CORE ID
START END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATE/TIME DATE/TIME (fcnoftest) (pslg) (deg F) (fps)
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
9 PER TEST
030894:1.1,270,0
021894:5:0.0.6
031794:1:1.90.0
021294:3:1.0.6
0218943:1.180,6
021294:3:1,90,6
030894:1:0.0.0
021894:5:1.90.6
021294:3:1.180.6
06/02/94 14:13
30.7
31.52
36.03
35.04
39.49
37.45
113.03
41.19
42.56
06/05/94 14:12*
427763.03
341927.5
255314.84
255510.13
428281.25
341931.94
341837.44
341822.19
341859.81
427732.33
341895.98
255278.81
255475.09
428241.76
341894.49
341724.41
341781
341817.25
AVERAGE
49.9
49.9
49.9
49.9
49.9
49.9
49.9
49.9
49.9
AVERAGE
74.6
74.6
74.6
75.1
75.1
75.1
74.7
74.7
74.7
AVERAGE
0
0
0
0
0
0
0
0
0
-------
Table H8 5 M&P test data, artificial sandstone, nominal 500 md permeability.
M&P TEST
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
H20 WEIGHT
(am)
9 PER TEST
591.5
529.7
491.6
345.3
413.2
510.3
85.4
67.0
185.4
H2O VIS.
(CD)
9 PER TEST
0.931
0.931
0.931
0.925
0.925
0.925
0.930
0.930
0.930
M&P CORE "L" CORE "Ac"
ID (cm) (crrTcm) GAS I ini nn
9 PER TEST
1.1
1.2
1.3
2.1
22
2.3
3.1
3.2
3.3
9 PER TEST
3.498
3.500
3.531
3.513
3.500
3.500
3.510
3.493 '
3.518
9 PER TEST
5337
5.351
5.463
5.355
5.365
5.355
5.344
5.358
5.355
PERMEABILITY
535.8
5328
531.3
528.9
5098
506.7
496.3
490.6
4688
PERMEABILITY
0.2487
0.2781
0.3415
0.2415
0 1715
0.2658
0.0450
00350
00976
a>
en
-------
Table H8.6 M&P test data, artificial sandstone, nominal 500 md permeability
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
INS 06/05/94: 'Computer disk full at some point before this time.
INS 06/04/94: 08:53: Measured beaker wet weights of
subassembly #1 . Refilled subassembly #1 and replaced beakers.
INS 06/04/94: 19:27: Measured beaker wet weights of
subassemblv #2. Refilled subassembly #2 and replaced beakers.
INS 06/05/94: 14:12: Disk full; filled subassembly #3 with water e
comp. time=82747.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4 BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
-------
Table H9 1 M&P test data, natural sandstone, Pony Creek Shale, nominal 1250 md permeability.
M&P TEST
CORE ID
START END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATE/TIME DATE/TIME (fen of test) (pslg) (deg F) (fosl
PHASE
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
9 PER TEST
PC11A
PC14C
PC6B
PC14B
PC7C
PC10B
PC8B
PC12C
PC13B
PC11A
PC14C
PC6B
PC14B
PC7C
PC10B
PC8B
PC12C
PC13B
06/07/94 14:20
315.16
316.53
318.45
320.43
321.53
322.79
324.99
326.09
327.13
06/07/94 15:15
351.30
352.29
353.50
355.80
356.79
357.51
358.93
359.54
361.29
06/07/94
398.86
425.17
394.20
398.81
321.86
385.52
398.08
425.34
394.36
06/08/94 15:15
86732.51
86737.73
86739.33
86679.57
86764.11
86729.55
86699.01
86727.41
86730.81
83.70
108.64
75.75
78.38
0.33
62.73
71.07
99.25
67.23
86381.21
86385.44
86385.83
86323.77
86407.32
86372.04
86340.08
86367.87
86369.52
AVERAGE
28.7
28.7
28.7
28.7
28.7
28.7
28.7
28.7
28.7
50.5
50.5
50.5
50.5
50.5
50.5
50.5
50.5
50.5
AVERAGE
70.8
70.8
70.6
71.2
71.2
71.2
72
72
72
90.0
90.0
90.0
90.0
90.0
90.0
90.0
90.0
90.0
AVERAGE
0
0
0
0
0
0
0
0
0
1.63
1.63
163
1.63
1.63
1.63
1.63
1.63
1 63
o>
-------
Table H9 2 M&P lest data, natural sandstone. Pony Creek Shale, nominal 1250 md permeability.
M&P TEST
PHASE
H2O PERM
H2O PERM
H2O PERM
H20 PERM
H20 PERM
H2O PERM
H2O PERM
H2O PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
H20 WEIGHT
(am)
9 PER TEST
194.6
97.9
193.9
226.8
213.6
196.5
208.5
22.7
199.9
88.3
93.8
91.6
309
22.0
34.3
14.3
14.9
12.3
H2O VIS.
(CD)
9 PER TEST
0.988
0.988
0.988
0.979
0.979
0.979
0.968
0.968
0.968
0.750
0.750
0.750
0.750
0.750
0.750
0.750
0.750
0.750
M&P CORE "L" CORE "Ac"
ID (cm) (cm*cm) GAS LIQUID
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
1.1
1.2
1.3
21
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.500
3.510
3.487
3.508
3.505
3.493
3.505
3.503
3.505
3.500
3.510
3.487
3.508
3.505
3.493
3.505
3.503
3.505
9 PER TEST
5.344
5.327
5.268
5.303
5.334
5.317
5.324
5.306
5.310
5.344
5.327
5.268
5.303
5.334
5.317
5.324
5.306
5.310
PERMEABILITY
1228.7
1230.9
1252.6
1257.7
1258.0
1260.6
1261.5
1262.4
1262.5
1228.7
1230.9
1252.6
1257.7
1258.0
1260.6
1261.5
1262.4
1262.5
PERMEABILITY
770.47
300.45
857.38
959.89
213316.06
1031.89
957.31
74.83
972.81
0.1461
0.1562
0.1532
00517
0.0365
0.0569
0.0238
0.0249
0.0205
0)
00
-------
Table H9 3 M&P test data, natural sandstone, Pony Creek Shale, nominal 1250 md permeability.
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
H20 PERM
H20 PERM
H2O PERM
H2O PERM
H20 PERM
H20 PERM
H2O PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
H20 PERM 06/07/94: 14:20: 1.2 shut off at 100 mL 3.2
shut off at 50 ml.
Anomalous comp. run time = .33 sec., resulting In large
liquid permeability value.
MCB 08/07/94: 16:04 Photo cell on drip tube 2.2 moved
down, due to the drip activating the photo cell before
the drip fell.
MCB 06/08/94: 11:27: Comp time 72750: Photo cell 1.1
stuck on.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3 BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5 COMPUTER MEMORY FILLED
6 PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
at
to
-------
Table H9 4 M&P test data, natural sandstone, Pony Creek Shale, nominal 1250 md permeability.
M&P TEST
CORE ID
START
DATEmME
END
DATEmME
RUNTIME PRESSURE TEMPERATURE FLOW RATE
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
_
9 PER TEST
PC11A
PC14C
PC6B
PC14B
PC7C
PC10B
PC8B
PC12C
PC13B
06/08/94 15.35
105.56
107.43
108.86
110.78
153.18
113.14
115.01
116.11
118.80
06/11/94 15:18
257628.95
257629.75
257640.88
257645.44
257653.42
257575.59
257657.00
257658.41
257599.05
257523.39
257522.32
257532.02
257534.66
257500.24
257462.45
257541.99
257542.30
257480.25
AVERAGE
49.8
49.8
49.8
49.8
49.8
. 49.8
49.8
49.8
49.8
AVERAGE
76.1
76.1
78.1
76.4
78.4
764
75.8
75.8
75.8
• Vf"l
AVERAGE
0
0
0
0
0
0
0
0
0
^1
o
-------
Table H9.5 M&P lest data, natural sandstone. Pony Creek Shale, nominal 1250 md permeability.
M&P TEST
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
H2O WEIGHT H2OVIS. M&P CORET1 CORE "Ac"
(am) (cp) ID (cm) (cm*cm) GAS LIQUID
9 PER TEST
221.6
201.8
229.0
191.4
208.6
149.0
68.1
55.9
53.1
9 PER TEST
0.911
0.911
0911
0907
0.907
0.907
0.915
0.915
0.915
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.500
3.510
3.487
3.508
3.505
3.493
3.505
3.503
3.505
9 PER TEST
5.344
5.327
5.268
5.303
5.334
5.317
5.324
5.306
5.310
PERMEABILITY
1228.7
1230.9
1252.6
1257.7
12580
1260.6
1261.5
1262.4
1262.5
PERMEABILITY
0.1516
0.1389
0.1584
0.1317
0.1426
0.1018
0.0470
00387
00368
I
-J
-------
Table H9 6 M&P test data, natural sandstone, Pony Creek Shale, nominal 1250 md permeability.
M&P TEST
PHASE
INS
INS
INS
INS
INS
INS
•si
ro
INS
INS
INS
ANY APPROPRIATE COMMENT
INS 06/11/94: Comp. time 6700: Subassemblv #1 refilled
with water.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
8. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
-------
Table H10.1 M&P test data, natural sandstone, Hughes Creek Shale, nominal 200 md permeability.
M&P TEST
CORE ID
START END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATEATIME DATE/TIME (fcnoftest) (pslg) (deg F) (fps)
PHASE
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
9 PER TEST
9BHC
12AHC
6BHC
13BHC
14BHC
5BHC
7BHC
16BHC
15AHC
9BHC
12AHC
6BHC
13BHC
14BHC
5BHC
7BHC
16BHC
15AHC
06/21/94 11.44
48.02
46.96
49.26
53.27
54.54
55.14
56.62
57.94
59.59
06/21/94 14:11
280.72
281.71
286.54
285.50
286.43
287.48
288.96
290.50
291.10
06/21/94
487.95
630.16
474.33
560.45
1347.15
440.16
639.55
1346.93
1076.37
08/22/94 14:39
87801.31
87932.32
87876.34
87901.04
87820.48
87909.79
87838.21
87942.20
87942.20
441.93
583.20
425.07
507.18
1292.81
385.02
582.93
1288.99
1016.78
87520.59
87650.61
87589.80
87615.54
87534.05
87622.31
87549.25
87651.70
87651.10
AVERAGE
29.2
29.2
29.2
29.2
29.2
29.2
29.2
29.2
29.2
50.8
50.8
50.8
50.8
50.8
50.8
50.8
50.8
50.8
AVERAGE
71.0
71.0
71.0
71.2
71.2
71.2
71.7
71.7
71.7
92.3
92.3
92.3
92.3
92.3
92.3
92.3
92.3
92.3
AVERAGE
0
0
0
0
0
0
0
0
0
1.62
1.62
1.62
1 62
1.62
1.62
1.62
1.62
1.62
->l
W
-------
Table H10 2 M&P lest data, natural sandstone. Hughes Creek Shale, nominal 200 md permeability.
H2O WEIGHT H2OVIS. M&P CORET" CORE "Ac"
M&P TEST (am) (cp) ID (cm) (cm'cm) GAS LIQUID
PHASE
H20 PERM
H2O PERM
H2O PERM
H20 PERM
H2O PERM
H20 PERM
H2O PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
9 PER TEST
192.7
189.3
196.6
194.3
192.9
193.8
198.7
187.8
206.4
59.9
66.0
52.5
28.5
28.1
31.3
23.5
21.5
22.6
9 PER TEST
0.982
0.982
0.982
0.979
0979
0.979
0.972
0.972
0.972
0.727
0.727
0.727
0.727
0.727
0.727
0.727
0.727
0.727
9 PER TEST
1.1
1.2
1.3
2.1
22
2.3
3.1
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3498
3.498
3.508
3.490
3.498
3.508
3.505
3.505
3.495
3.498
3.498
3.508
3.490
3.498
3.508
3.505
3.505
3.495
9 PER TEST
5.292
5.210
5.128
5.275
5.244
5.348
5.334
5.179
5.306
5.292
5.210
5.128
5.275
5.244
5.348
5.334
5.179
5.306
PERMEABILITY
242.7
238.4
237.3
236.5
2352
229.6
195.3
193.7
189.8
2427
238.4
237.3
236.5
235.2
229.6
195.3
193.7
189.8
PERMEABILITY
142.47
107.73
156.42
124.94
4906
162.74
109.60
48.25
65.42
0.0952
0.1063
0.0863
00453
0.0450
0.0493
0.0371
0.0349
00357
-------
Table H10.3 M&P test data, natural sandstone, Hughes Creek Shale, nominal 200 md permeability.
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
H20 PERM
H2O PERM
H2O PERM
H20 PERM
H20 PERM
H2O PERM
H20 PERM
H2O PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
Cores 3.1, 3.2, & 3.2 were Intentionally of lower permeability
due to a shortage of cores.
MCB 08/21/94: Comp. time 280: Drip tubes opened.
MCB 08/22/94: Comp. time 35180: Photo cell 1.2 stuck on.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4 BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
•>J
Ol
-------
Table H10 4 M&P test data, natural sandstone. Hughes Creek Shale, nominal 200 md permeability.
M&P TEST
CORE ID
START
DATE/TIME
END
DATE/TIME
RUNTIME PRESSURE TEMPERATURE FLOW RATE
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
INS 40
INS 40
INS 40
INS 40
INS 40
INS 40
INS 40
INS 40
INS 40
9 PER TEST
9BHC
12AHC
6BHC
13BHC
14BHC
5BHC
7BHC
16BHC
15AHC
9BHC
12AHC
8BHC
13BHC
14BHC
5BHC
7BHC
16BHC
15AHC
06/22/94 14.51
118.25
168.23
121.00
122.86
123.58
124.62
126.05
127.31
128.69
08/24/94 10:02
42.67
35.20
82.38
70.19
54.70
118.36
2.25
0.21
60.85
06/24/94 09:55
155000.63
154988.28
154858.34
154998.89
154742.63
154848.59
155021.72
154982.30
154974.02
06/24/94
12299.74
12301.05
12336.15
12276.23
12216.80
12249.70
12347.36
12331.21
12334.12
154882.38
154800.05
154737.34
154876.03
154619.05
154723.97
154895.67
154854.99
154845.33
12257.07
12265.85
12253.77
12206.04
12162.10
12131.34
12345.11
12331.00
12273.27
• «""Mf
AVERAGE
49.9
49.9
49.9
49.9
49.9
49.9
49.9
49.9
49.9
39.8
39.8
39.8
39.8
39.8
39.8
39.8
39.8
39.8
l"^M ' 1
AVERAGE
65.9
65.9
65.9
66.6
66.6
666
67.1
67.1
67.1
72.4
72.4
72.4
72.8
728
72.8
72.1
72.1
72.1
. i'M»i
AVERAGE
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
I
-«J
0)
-------
Table H10 5 M&P lest data, natural sandstone, Hughes Creek Shale, nominal 200 md permeability
H2O WEIGHT H2O VIS. M&P CORE "L" CORE "Ac"
M&P TEST (am) (CD) ID (cm) (cm'cm) GAS LIQUID
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
INS 40
INS 40
INS 40
INS 40
INS 40
INS 40
INS 40
INS 40
INS 40
9 PER TEST
139.1
127.4
116.6
319.6
85.0
184.0
236.0
98.6
43.5
6.2
5.5
56
6.2
3.7
4.5
7.6
5.9
3.2
9 PER TEST
1.059
1.059
1.059
1.048
1.048
1.048
1.040
1.040
1.040
0.962
0.962
0.962
0.956
0.956
0.956
0.966
0.966
0.966
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.498
3.498
3.508
3.490
3.498
3.508
3.505
3.505
3.495
3.498
3.498
3.508
3.490
3.498
3.508
3.505
3.505
3.495
9 PER TEST
5.292
5.210
5.128
5.275
5.244
5.348
5.334
5.179
5.306
5.292
5.210
5.128
5.275
5.244
5.348
5.334
5.179
5.306
PERMEABILITY
242.7
238.4
237.3
236.5
235.2
229.6
195.3
193.7
189.8
242.7
238.4
2373
236.5
235.2
229.6
195.3
193.7
189.8
PERMEABILITY
0.1852
01724
0.1608
0.4216
0.1132
0.2409
0.3069
0.1321
0.0567
0.1188
0.1070
01111
0.1187
0.0717
0.0859
0.1444
0.1156
0.0613
-------
Table H10 6 M&P test data, natural sandstone, Hughes Creek Shale, nominal 200 md permeability
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
INS 40
INS 40
INS 40
INS 40
INS 40
INS 40
INS 40
INS 40
INS 40
INS 06/23/94: 08:00: Photo cell 2.1 stuck on.
INS 06/23/94: 17:26: Photocell 1.1 stuck on.
INS 06/24/94. Photo cell 3.3 flickering on and off.
INS IPS 40 06/24/94: 10:09: Comp. time 470: Changed to
250 ml beakers.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2 FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4 BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
->l
00
-------
Table H10 7 M&P test data, natural sandstone, Hughes Creek Shale, nominal 200 md permeability.
M&P TEST
CORE ID
START
DATE/TIME
END
DATE/TIME
RUNTIME PRESSURE TEMPERATURE FLOW RATE
PHASE
INS 30
INS 30
INS 30
INS 30
INS 30
INS 30
INS 30
INS 30
INS 30
INS 20
INS 20
INS 20
INS 20
INS 20
.INS 20
INS 20
INS 20
INS 20
9 PER TEST
9BHC
12AHC
6BHC
13BHC
14BHC
5BHC
7BHC
16BHC
15AHC
9BHC
12AHC
6BHC
13BHC
14BHC
5BHC
7BHC
16BHC
15AHC
06/24/94 13:38
57.58
83.15
36.30
61.51
338.23
210.63
42.07
287.65
131 32
08/24/94 16:34
172.19
83.43
164.55
9.86
152.96
867.43
7.52
74.38
165.87
06/24/94 16.27
10069.05
10024.28
10106.45
10158.63
10081.19
10049.49
10187.58
10121.06
10073.22
06/24/94 19:39
10755.23
10681.03
10847.45
10809.83
10843.00
10796.64
11013.49
10926.21
10989.54
10011.49
9941.13
10070.15
10097.12
9722.96
9838.86
10125.51
9853.41
9941.90
10583.04
10577.60
10682.90
10800.17
10690.04
9929.21
11005.97
10851.85
10823.67
AVERAGE
29.9
29.9
29.9
29.9
29.9
29.9
29.9
29.9
29.9
19.9
19.9
19.9
19.9
19.9
19.9
19.9
19.9
19.9
AVERAGE
75.2
75.2
75.2
75.8
75.8
75.8
75.9
75.9
759
71.2
712
71 2
71.8
71.8
71.8
72.3
72.3
72.3
AVERAGE
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
->J
to
-------
Table H10.8 M&P test data, natural sandstone, Hughes Creek Shale, nominal 200 md permeability.
H2O WEIGHT H2O VIS. M&P CORE1!" CORE "Ac"
M&P TEST (am) (cp) ID (cm) (cm'cm) GAS LIQUID
PHASE
INS 30
INS 30
INS 30
INS 30
INS 30
INS 30
INS 30
INS 30
INS 30
INS 20
INS 20
INS 20
INS 20
INS 20
INS 20
INS 20
INS 20
INS 20
9 PER TEST
3.0
2.7
3.0
3.1
1.8
2.4
2.9
3.2
1.8
2.0
1.7
2.1
1.3
1.3
1.7
2.0
2.6
1.2
9 PER TEST
0.923
0.923
0.923
0.915
0.915
0.915
0.914
0.914
0.914
0.979
0.979
0979
0.971
0.971
0.971
0.983
0.963
0.963
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.498
3.496
3.508
3.490
3498
3.508
3.505
3.505
3.495
3.498
3.498
3.508
3.490
3.498
3.508
3.505
3.505
3.495
9 PER TEST
5.292
5.210
5.128
5.275
5.244
5.348
5.334
5.179
5.306
5.292
5.210
5.128
5.275
5.244
5.348
5.334
5.179
5.306
PERMEABILITY
242.7
238.4
237.3
236.5
235.2
229.6
195.3
193.7
189.8
242.7
238.4
237.3
236.5
235.2
229.6
195.3
193.7
189.8
PERMEABILITY
0.089908
0.082772
0092511
0.091411
0 055567
0.072001
0.084576
0.098773
0 053591
0.090338
0.078036
0 097256
0.057092
0.058148
0.080508
0.084983
0.115401
0.051971
X
00
o
-------
Table H10 9 M&P test data, natural sandstone, Hughes Creek Shale, nominal 200 md permeability.
M&P TEST
ANY APPROPRIATE COMMENT
PHASE
INS 30
INS 30
INS 30
INS 30
INS 30
INS 30
INS 30
INS 30
INS 30
INS 20
INS 20
INS 20
INS 20
INS 20
INS 20
INS 20
INS 20
INS 20
INS IPS 30 06/24/94: Photo cell 2.2 stuck on.
INS IPS 30 06/24/94: Worked on OHAUS Scale as it was
not recording water weights. Any weights recorded In the
computer file were due to the operators 'examining the Ohaus seal
EXAMPLE COMMENTS
1 SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
00
-------
Table H10.10 M&P test data, natural sandstone. Hughes Creek Shale, nominal 200 md permeability.
M&P TEST
CORE ID
START END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATE/TIME DATE/TIME (fen of test) (pslg) (deg F) (fps)
PHASE
INS 10
INS 10
INS 10
INS 10
INS 10
INS 10
INS 10
INS 10
INS 10
9 PER TEST
9BHC
12AHC
6BHC
13BHC
14BHC
5BHC
7BHC
16BHC
15AHC
06/24/94 19:48
236.61
72.50
165.60
867.71
212.56
169.44
281.16
213.71
387.33
06/25/94 07:58
43699.43
43468.14
43588.15
43828.51
43215.54
43728.10
43830.70
43806.48
43814.06
43462.82
43395.64
43422.55
42960.80
43002.98
43558.66
43549.54
43592.77
43426.73
AVERAGE
9.8
9.8
9.8
9.8
9.8
9.8
9.8
9.8
9.8
AVERAGE
75.0
75.0
75.0
75.2
75.2
75.2
74.6
74.6
74.6
AVERAGE
0
0
0
0
0
0
0
0
0
I
00
to
-------
Table H10.11 M&P test data, natural sandstone, Hughes Creek Shale, nominal 200 md permeability
M&P TEST
PHASE
INS 10
INS 10
INS 10
INS 10
INS 10
INS 10
INS 10
INS 10
INS 10
H20 WEIGHT
(am)
9 PER TEST
2.8
18
32
2.1
1.7
2.2
3.8
10.8
2.1
H20 VIS.
(CD)
9 PER TEST
0.926
0.926
0.926
0.923
0.923
0.923
0.931
0.931
0.931
M&P CORE "L" CORE "Ac"
ID (cm) (cm'crrri GAS i inrun
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
3.498
3.498
3.508
3.490
3.498
3.508
3.505
3.505
3.495
9 PER TEST
5.292
5.210
5.128
5.275
5.244
5.348
5.334
5.179
5.308
PERMEABILITY
242.7
238.4
237.3
236.5
235.2
229.6
195.3
193.7
189.8
PERMEABILITY
0.0591
0.0387
00700
0.0448
00365
0.0459
0.0801
0.2343
0.0445
09
W
-------
Table H10.12 M&P test data, natural sandstone, Hughes Creek Shale, nominal 200 md permeability.
M&P TEST
PHASE
INS 10
INS 10
INS 10
INS 10
INS 10
INS 10
INS 10
INS 10
INS 10
ANY APPROPRIATE COMMENT
EXAMPLE COMMENTS
1 . SENSOR PROBLEMS
2 FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4. BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6. PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
-------
Table H11 1 M&P test data, artificial sandstone, 0.9 - 2.7 md permeability.
M&P TEST
CORE ID
START END RUNTIME PRESSURE TEMPERATURE FLOW RATE
DATE/TIME DATEmME (fen of test) (pslg) (deg F) (fps)
PHASE
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
H20 PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
9 PER TEST
AR-2:1.270.P
AR-2:1,0,A
AR-2.0.0.B
AR-2:1.90.D
AR-2:O.O.O
AR-2.1.270.K
AR-2:1.90.M
AR-2:1.180.G
AR-2.1. 180.1
AR-2:1.270.P
AR-2:1.0.A
AR-2:O.O.B
AR-2:1.90.D
AR-2:O.O.O
AR-2:1.270.K
AR-2:1.90.M
AR-2:1.180.G
AR-2:1. 180.1
11/16/94 12:01
291.26
292.58
294.23
295.77
298.79
301.26
303.24
304.67
306.00
11/18/94 19:20
172.96
174.22
176.58
177.02
178.23
181.08
183.50
183.17
185.97
11/16/94 12:04
330.98
342.57
34872
361.24
355.03
363.22
397.33
380.19
399.00
11/19/94 00.33
18909.03
18903.04
18919.91
18797.48
18905.79
18913.86
18942.53
18873.16
18937.87
39.72
49.99
5449
65.47
56.24
61.96
94.09
75.52
93.00
18736.07
18728.82
18743.33
18620.46
18727.58
18732.78
18759.03
18689.99
18751.90
AVERAGE
28.7
28.7
287
28.7
28.7
28.7
28.7
28.7
28.7
50.8
50.8
508
50.8
50.8
50.8
50.8
50.8
50.8
AVERAGE
72.8
72.8
72.8
72.4
72.4
72.4
71.5
71.5
71.5
59.5
59.5
59.5
59.5
59.5
59.5
59.5
595
59.5
AVERAGE
0
0
0
0
0
0
0
0
0
1.79
1.79
1.79
1.79
1.79
1.79
1.79
1.79
1.79
I
00
01
-------
Table H11 2 M&P test data, artificial sandstone. 0.9 - 2.7 md permeability
H2O WEIGHT H2O VIS. M&P CORE "L"
M*PTPST forrrt (CD) ID (cm)
PHASE
H2O PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
9 PER TEST
287.7
290.3
292 2
291.4
311.0
294.6
296.1
285.9
294.2
41.5
36.7
26.6
7.2
10.6
26.4
12.9
12.6
13.1
9 PER TEST
0.956
0.956
0.956
0.962
0.962
0.962
0.975
0.975
0.975
1.166
1.166
1 166
1.166
1.166
1.166
1.166
1.166
1.168
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
1.369
1.371
1.370
1.370
1.374
1.374
1.372
1.375
1.374
1.369
1.371
1.370
1.370
1.374
1.374
1.372
1.375
1.374
CORE "Ac"
(cm*cm)
9 PER TEST
5.393
5.372
5.376
5.386
5.386
5.393
5.390
5.390
5.390
5.393
5.372
5.376
5.386
5.386
5.393
5.390
5.390
5.390
GAS
PERMEABILITY
2719.3
2246.0
1997.5
1904.8
1803.3
1578.1
1280.0
1256.3
919.9
2719.3
2246.0
1997.5
19048
1803.3
1578.1
1280.0
1256.3
919.9
LIQUID
PERMEABILITY
900.65
725.97
669.39
557.84
695.09
59687
399.96
482.19
402.64
0.1897
0.1687
0.1220
0.0332
0.0487
0.1211
0.0591
00580
0.0601
-------
Table H11.3 M&P test data, artificial sandstone, 0.9 - 2.7 md permeability
M&P TEST ANY APPROPRIATE COMMENT
PHASE
H2O PERM
H20 PERM
H20 PERM
H20 PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
H2O PERM
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
MCB
400 ml filled to 300 ml
MCB 11/18/94: 21:54: Como. time 9285: Photo cell 3.1 stuck on.
EXAMPLE COMMENTS
1. SENSOR PROBLEMS
2. FLOW BREAK THROUGH
3. BEAKER OVERFLOW
4 BEAKER CHANGE DURING TEST
5. COMPUTER MEMORY FILLED
6 PRESSURE OR TEMPERATURE
IDIOSYNCRASIES
I
00
-------
Table H11.4 M&P test data, artificial sandstone, 0.9 - 2.7 md permeability.
00
00
M&P TEST
PHASE
IMC
IN<5
IM
-------
Table H11.5 M&P test data, artificial sandstone, 0.9 - 2.7 md permeability.
H2O WEIGHT H2O VIS. M&P CORE "L" CORE "Ac"
M&P TEST (am) (CD) ID (cm) (cm*cm) GAS LIQUID
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
9 PER TEST
287.1
219.8
226.2
55.6
72.0
109.3
97.0
40.0
583
9 PER TEST
1.069
1.069
1.087
1.059
1.059
1.059
1.061
1.061
1.061
9 PER TEST
1.1
1.2
1.3
2.1
2.2
2.3
3.1
3.2
3.3
9 PER TEST
1.369
1.371
1.370
1.370
1.374
1.374
1.372
1.375
1.374
9 PER TEST
5.393
5.372
5.376
5.386
5.386
5.393
5.390
5.390
5.390
PERMEABILITY
2719.30
2246.00
1997.50
1904.80
1803.30
1578.10
1280.00
1256.30
919.90
PERMEABILITY
1 1791
0.8937
0.4790
00765
00994
0.1507
0.1341
0.0553
0.0805
09
CO
-------
Table H11 6 M&P test data, artificial sandstone, 0.9 - 2.7 md permeability.
I
CD
O
M&P TEST ANY APPROPRIATE COMMENT
PHASE
INS
INS
INS
INS
INS
INS
INS
INS
INS
-------
APPENDIX I
POROSITY AND PERMEABILITY: CORE PLUGS
INTRODUCTION
In preparation for analysis in the Mud-cake and Permeability system, several
hundred core plugs were analyzed for permeability to nitrogen; the instrument used
was a Ruska permeameter. Of this set of hundreds, two representative subsets were
chosen: 99 plugs were tested for mud-cake buildup and permeability to water, and for
the purpose of independent checking, 32 plugs were analyzed at the OSU laboratory,
then sent to K & A Laboratories, Tulsa, Oklahoma, for comparative analyses. These
32 plugs were a fair sample with attributes strongly similar to those of the set of 99
plugs described above. Properties evaluated by K & A were grain density, porosity,
permeability to nitrogen, and permeability to water. In the collection of 32 plugs, 12
were samples of natural sandstone; the remainder were artificial rock composed of
quartz sand and epoxy.
Samples of artificial sandstone analyzed for permeability to nitrogen at
Oklahoma State University were not dried by heating. Likewise, no attempt was made
to dehydrate core plugs of natural sandstone, but in all cases the rock was regarded
as having been dried appropriately under room conditions. The set of 32 samples
analyzed by K & A Laboratories were dried in an oven at 220 deg. F. for 24 hrs.
Figure 11 shows that in 30 of 32 samples, permeability measured by K & A was
greater than permeability measured at Oklahoma State University. (See "diamond"
curve, Figure 11. Data shown in Table 11; samples of natural sandstone are identified
by prefixes "PC," "RS," and "HC.")
The value of comparative analyses is to address these questions: (1) Of the 32
samples analyzed, are estimates of porosity made by the OSU laboratory significantly
different from measurements made by K & A Laboratories? (2) Of the remaining
scores of samples analyzed by the OSU laboratory (Appendix M), are estimates of
porosity made by the OSU laboratory significantly different from measurements that
would be made by K & A Laboratories? (3) Are estimates of permeability made by the
OSU laboratory significantly different from measurements that were made, or that
would be made, by K & A Laboratories?
11
-------
3500
3000 ;
2500 1
| 2000
Artifical
Natural Artificial
62194" "6194'
Natural
-61494'
Artificial Artificial
•sa&rVsiBw"
Natural
6794
Artificial
' -51194-'
& /!
5394 /
/ !
Number of Cores
OSU Nitrogen Permeabilty
K&A Air Permeability
Difference
Figure 11. Comparison of permeability measurements by OSU laboratory and K & A
Laboratories. Observe divergence of measurements toward samples with
high porosity. Observe also that measurements converge among samples
of natural sandstone. Data suggest differential effects of heat-drying of
samples. Data shown in Table 11.
12
-------
TABLE 11 CORE-PLUG ANALYSES, K & A LABORATORIES
Column 1: Core-plug number, as shown in Figure 11. Column 2: Grain density,
gm/cm-3. Column 3: Porosity, percent, K & A Laboratories. Column 4: Porosity,
percent, OSU laboratory, computed from scaled measurements and grain densities
reported by K & A Laboratory. Column 5: Porosity, percent, OSU laboratory, computed
from scaled measurements and average grain densities, artificial sandstone (2.374
grn/cm-3), and natural sandstone (2.656 gm/cm3). Column 6: Permeability to nitrogen,
millidarcies, K & A Laboratory. Column 7: Permeability to nitrogen, millidarcies, OSU
laboratory. Column 8: Differences of permeabilities (Column 6 - Column 7),
millidarcies. Column 9: Permeability, percent difference. Note: Last 12 rows show data
concerning samples of natural sandstone.
8
9
6
5
7
13
16
20
17
14
15
18
19
8
27
28
26
25
29
30
31
32
1
2
3
4
11
10
21
23
9
24
12
22
2.2
2.26
2.33
2.36
2.37
2.36
2.37
2.36
2.36
2.38
2.37
2.38
2.37
2.38
2.38
2.37
2.4
2.4
2.4
2.39
2.65
2.65
2.65
2.65
2.66
2.66
2.65
2.66
2.65
2.67
2.66
2.66
9
10.9
14.6
15.6
15.6
15.8
16.2
16.3
16.3
16.6
17.1
17.3
17.4
17.4
17.7
17.9
18
18.8
18.9
19.2
22.8
23.6
24
25.1
25.7
26.2
26.3
26.5
26.7
27.1
27.2
27.2
9.97
11.44
14.88
15.55
15.85
16.25
16.3
16.6
16.49
17.34
17.7
17.66
18.16
17.75
18.15
18.13
18.29
18.86
18.98
19.77
23.56
24.09
24.44
25.42
26.36
27.26
26.89
27.74
27.3
28.22
30.19
27.94
16.75
15.69
16.46
16.05
15.99
16.74
16.44
17.09
16.98
17.13
17.84
17.46
18.3
17.55
17.94
18.27
17.4
17.97
18.09
19.23
23.73
24.26
24.61
25.59
26.25
27.16
27.06
27.63
27.46
27.84
30.09
27.83
12.3
685
760
1200
1240
1600
1450
914
1240
1490
1700
2260
2000
1980
2170
1870
2340
2290
2460
3060
174
191
185
191
718
734
1260
1400
649
1410
770
1360
465.8
457.6
573.7
967.7
1031.4
1302.6
1178.5
973.1
1028.4
1192.8
1301.7
574.3
1528.1
1528.9
1475.5
1473.1
1961.5
1973.9
2010.2
2047.6
155.3
159.7
165.8
180.6
603.6
589.6
1210.6
1312.4
536.5
1316.9
628.3
1285.7
-453.5
227.4
186.3
232.3
208.6
297.4
271.5
-59.1
211.6
297.2
398.3
1685.7
471.9
451.1
694.5
396.9
378.5
316.1
449.8
1012.4
18.7
31.3
19.2
10.4
114.4
144.4
49.4
87.6
112.5
93.1
141.7
74.3
-3686.99
33.20
24.51
19.36
16.82
18.59
18.72
-6.47
17.06
19.95
23.43
74.59
23.60
22.78
32.00
21.22
16.18
13.80
18.28
33.08
10.75
16.39
10.38
5.45
15.93
19.67
3.92
6.26
17.33
6.60
18.40
5.46
13
-------
ESTIMATES OF POROSITY
THE SET OF 32 CORE PLUGS
Comparison of two data-sets of porosity is based on Table 11, columns 4 and 5.
Measurements of porosity by the OSU laboratory were based on individual grain
densities reported by K & A Laboratories. Bulk density of each core plug was derived
from three measurements of diameter and one measurement of length. Summary
statistics are as follows:
Estimates of porosity, Oklahoma State:
Number of samples 32
Average porosity: 20.4228 percent
Standard deviation: 5.2688 percent
Variance: 27.7599
Measurement of porosity, K & A Laboratories:
Number of samples: 32
Average porosity: 19.8438 percent
Standard deviation: 5.0089 percent
Variance: 25.8967
Clearly, measurements of porosity made by the OSU laboratory are the greater
by approximately 0.6 of 1 percent (absolute), and by the ratio of about 1.03.
Measurements made by the OSU laboratory are somewhat more variable and
uniformly are slightly the larger (cf. Table 11, columns 4 and 5), the latter fact
suggesting a slight positive bias in measurement of volumes of core plugs.
To evaluate the significance of such difference requires consideration of the
effects of using porosity-data in the context of this research, and the question can be
reduced as follows. Assume that measurements of porosity by K & A Laboratories are
taken to be the truth or a close approximation of the truth. Then were measurements
of porosity by the OSU laboratory so distant from the mark that they would invalidate
conclusions drawn from use of the core plugs in Mud-cake and Permeability tests? Or
would they bias seriously the inferences to be drawn from Mud-cake and Permeability
tests and extended to predictions of behavior of reservoirs in the subsurface? The
answer is "no," because unpreventable errors of greater proportion arise elsewhere in
the total chain of experiments; the average error of 0.6 percent porosity is of no
operational significance.
14
-------
THE SET OF 99 CORE PLUGS
This question was asked in passages above: Of the 99 samples analyzed by
the OSU laboratory (Appendix M), are estimates of porosity made by the OSU
laboratory significantly different from measurements that would be made by K & A
Laboratories?
In estimating porosity of the set of 99 core plugs from data compiled in the
course of work at Oklahoma State University (see also Appendix M), the averages of
matrix densities of artificial sandstone and of natural sandstone - as reported by K &
A Laboratories (Table 11) - were accepted as reliable approximations of mean matrix
densities of the two populations (Appendix M).
Artificial sandstone:
Number of samples: 18. (Core-plugs 5 and 6 were excluded; matrix densities
were judged to be unrepresentative of artificial
sandstone.)
Average matrix density: 2.3739 gm/cm3
Standard deviation: 0.0170 gm/cm3
Natural sandstone:
Number of samples: 12
Average matrix density: 2.6558 gm/cm3
Standard deviation: 0.0067 gm/cm3
Assume that measurements of porosity from the set of 32 core plugs would be
representative of all similar measurements to be made by the OSU laboratory and by
K & A Laboratories. Assume also that the OSU laboratory would estimate true matrix
densities of artificial sandstone and of natural sandstone as 2.374 gm/cu cm and
2/656 gm/cu cm, respectively; these numbers are means of matrix densities reported
by K & A Laboratories. The two data-sets (OSU cf. K & A) would be independent
estimates of the porosity of one population. Assume further that measurements of
porosity by K & A Laboratories are the truth or a close approximation of the truth.
Two working hypotheses arise: (1) No significant difference exists between the
averages of porosities computed by personnel at Oklahoma State and K & A
Laboratories; therefore no significant difference exists in the effectiveness of methods.
(2) A significant difference exists between the averages of porosities computed by
personnel at Oklahoma State and K & A Laboratories; therefore a significant
difference exists in the effectiveness of methods. If significant difference exists in this
single variable of porosity, the difference should be manifest in the variances of the
two sets of data, or in the means of the two sets of data, or both.
15
-------
Discrimination between the null and the alternate hypothesis by Student's t-test is
appropriate.
Estimates of porosity, Oklahoma State:
Number of samples: 32
Average porosity: 20.7775 percent
Standard deviation: 4.7813 percent
Variance: 22.8609
Measurement of porosity, K & A Laboratories:
Number of samples: 32
Average porosity: 19.8438 percent
Standard deviation: 5.0889 percent
Variance: 25.8967
The working hypothesis of equality of variances was evaluated by the variance-
ratio test:
F(sample) = Variance (K & A)/ Variance (OSU)
F(sample) = 25.8967/22.8609
F(sample) = 1.1328
F(0.05, 31,31) = 2.06 (very nearly)
F(sample) = 1.0951, not significant
No evidence described here requires the rejection of the proposition that the
variances of the two sets of samples of porosity are equal, having been computed
from one population or from two populations, neither of which is more variable than
the other; the observed variation would be expected to occur more than 25 times in
100 similar trials.
The working hypothesis of equality of means was tested by Student's T test:
t(sample) = ((ave. por., OSU) - (ave. por., K & A))/
((1/n (sum of variances))0-5), where"n" is 32.
t(sample) = 0.7564; 62 degrees of freedom
t(0.05, 62) = 2.0 (very nearly)
The probability of occurrence of the t-statistic of 0.75 is between 40 and 50 in
100 similar trials, if samples were drawn from a single population, or from populations
with equal means No evidence set out directly above requires the rejection of the
proposition that estimates of porosity by the two laboratories are effectively the same;
16
-------
that is, the two sets of estimates were drawn from one population with mean porosity
near 20% and standard deviation near 5 percent. However, inspection of Table 11,
columns 3 and 5 shows that 29 of 32 estimates of porosity by the OSU laboratory
were greater than measurements by K & A Laboratories. These data are consistent
with the trend toward slightly larger estimates by the OSU laboratory, a trend
described above and regarded as being real. The difference, on the average, is
approximately 0.9 percent porosity, an amount judged to be of no serious
consequence. The method of estimating porosity from average grain densities of
2.374 gm/cu cm (artificial sandstone) and 2.656 gm/cu cm (natural sandstone) is
considered to be sufficient for the purposes at hand.
ESTIMATES OF POROSITY, M & P TESTS
Core plugs of artificial sandstone were used in Mud-cake and Permeameter
tests with the expectation of reasoning from the results of such tests to draw
inferences about behavior of the large artificial reservoir of the Simulated Injection
System - and ultimately about behavior of natural reservoir rock. Considerable effort
was expended to learn to make artificial rock in cores of 5-in. diameter in a consistent
manner, so that core plugs from these small samples would have porosity and
permeability consistent with the large reservoir of the SIS system. However, variation
of porosity and permeability also was introduced to some degree, for one purpose of
the research was to reason by analogy from experiments with artificial sandstone to
predictions about reservoirs of natural sandstone. Of course, at the scale of field
operations, aquifers show much variation in porosity and permeability.
A large core was extracted from the SIS reservoir (Figure 4.14); 85 plugs from
this core were analyzed for porosity. The average porosity was 18.75 percent; the
standard deviation was 0.5787 percent. Fifty plugs from 5-in.-diameter cores (Figure
4.16) were evaluated in the Mud-cake and Permeameter system, with the expectation
that porosity and permeability would be similar to those of the large reservoir. The
average porosity was 17.05 percent; the standard deviation was 1.0841 percent.
Clearly the rock made in small batches is the more variable, but the average porosity
is about 0.9 that of the large reservoir. The rock made in small batches was
constituted with various proportions of epoxy and sand, and compacted in several
ways Its greater variation is a product of the empirical approach, in attempting to
stabilize the porosity and minimize the variation in porosity and permeability. The
central question is whether porosity is so different that conclusions drawn from Mud-
cake and Permeability tests cannot validly be extended to inferences about the SIS
reservoir.
17
-------
Estimates of porosity, SIS reservoir-
Number of samples: 85
Average porosity: 18.7488 percent
Standard deviation: 0.5787 percent
Variance: 0.3349
Measurement of porosity, M & P samples:
Number of samples: 50
Average porosity: 17.0509 percent
Standard deviation: 1.0835 percent
Variance: 1.1740
The hypothesis of equality of variances, evaluated by the variance-ratio test:
F(sample) = Variance (SIS)/ Variance (M&P)
F(sample) = 1.1740/0.3349
F(sample) = 3.5
F(0.02, 49,84) = 1.78 (approximately)
F(sample) = 3.5, quite significant
The variance-ratio test is strong evidence that variation of core-plugs from 5-in.
samples is much the greater, as expected from inspection of the basic statistics.
Whether the mean are significantly different can be estimated by Student's t-test, of
this form:
t(smpl.) = ((ave. por., SIS) - (ave. por., M&P))/
(((var., SIS)/85) + ((var, M&P)/50))0-5
t(smpl.) = (18.7488-17.0509)/((0.3349/85)+(1.1740/50))0-5
t(smpl.) = 10.22, which is highly significant, (tn.05 is approximately 2.01)
Thus the supposition that core plugs from the large artificial-sandstone
reservoir and core plugs from numerous cores 5-in. in diameter represent one
population must be rejected. The two kinds of rock are indeed different, especially
with respect to variation in porosity. The effort to approximate porosity of the large
artificial reservoir by sampling from small "reservoirs" was not successful. But the
question arises. "Is this conclusion is the result of extraordinarily large variation in the
M&P samples, or extraordinarily small variation of porosity in the SIS reservoir?"
The M&P samples could be considered to be extraordinarily variable if they are more
variable than natural sandstone; then their utility would be compromised.
18
-------
The 50 samples of artificial sandstone used in M & P tests are compared below
to samples of natural sandstone used in Mud-cake and Permeability tests:
Porosity, M & P samples, artificial rock:
lumber of samples: 50
Average porosity: 17.0509 percent
Standard deviation: 1.0835 percent
Variance: 1.17401
Porosity, M & P samples, natural sandstone:
Number of samples: 33
Average porosity: 26.0234 percent
Standard deviation: 2.7471 percent
Variance: 7.54649
If the sample of natural sandstones described here is considered to be a
representative collection of such rocks - as it probably is - then the core plugs of
artificial sandstone used in M & P tests are appreciably less varied; thus their
usefulness for qualitative reasoning about natural reservoirs seems to be established,
and by extension, so does the usefulness of the SIS artificial reservoir.
ESTIMATES OF POROSITY, M & P TESTS, WET CORE PLUGS
Porosities of core plugs used in M & P tests were calculated from dry-weights
and wet-weights. Summary statistics are shown below:
1 Artificial sandstone, 50 core plugs:
Porosity, dry Porosity, wet
Average: 17.05% Average: 21.42%
Std. deviation: 1.08% Std. deviation: 2.42%
2. Artificial sandstone, SIS reservoir, 9 core plugs:
Porosity, dry Porosity, wet
Average: 18.99% Average: 24.61 %
Std. deviation: 0.57% Std. deviation: 2.79%
19
-------
3. Natural sandstone:
Porositv. drv. 33 plugs Porositv. wet. 17 plugs
Average: 26.02% Average: 36.44%
Std. Deviation: 2.75% Std deviation. 5.03%
In each instance, wet-weight porosity is the greater, on the average; moreover,
wet-weight porosity is the more variable. In computation of wet-weight porosity, core-
plugs are assumed to be totally saturated. Because calculated porosity is a function
of bulk density, saturation of less than 100% of the pores would produce erroneously
large estimates of porosity. Data shown above lead to the conclusion that samples
were not completely saturated with water, although they were hydrated in a vacuum
chamber in each instance. In brief, dry-weight porosities are regarded as the better
estimates of true porosity.
ESTIMATES OF PERMEABILITY
PERMEABILITY TO NITROGEN
Permeabilities of the set of 32 samples were measured at both laboratories.
As a matter of routine query, the working hypothesis of equality of measurements was
entertained. Figure 11 indicates forcefully that measurements of permeability by K & A
Laboratories were systematically greater than measurements made by the OSU
laboratory, especially wherein permeability of artificial sandstone is concerned As
described above, before analysis by K & A Laboratories the core plugs were dried by
heating to 220° F., a treatment sufficient to mobilize the epoxy cement. On the
assumption that such drying changed configuration of pore throats and increased
permeability of the artificial sandstone, comparison of measurements was based on
data concerning natural sandstone. Drying of natural sandstone is a "treatment;" this
suggests that to evaluate the working hypothesis of equal results by paired
comparisons would be in order. Table 11, column 8, shows differences in
permeabilities of natural sandstones, wherein measurements by K & A Laboratories
uniformly are the greater. The hypothesis to be evaluated is that these differences
are a matter of chance. The paired-comparisons test is as follows:
Number of differences: 12 (Table 11)
Average difference: 74.75 millidarcies
Standard deviation of differences: 48.3656 md.
Standard error of differences: 13.96
t(sample) = (mean of differences)/(standard error of differences)
t(sample) = 74.75/13.96
t(sample) = 5.3546
t(0.001,11) = 4437
110
-------
If measurements of permeabilities of natural sandstones made by the two
laboratories were equal, and if the samples measured were identical, the probability
of a t-statistic of 5.355 having occurred by chance alone is less than 1 in 1000 similar
trials. One of these conclusions is warranted: (a) methods of analysis are significantly
different, (b) methods of analysis were essentially the same, but the samples
analyzed were not identical, or (c) methods of analysis were significantly different and
the samples analyzed were not identical. Methods of analysis seem to have been
similar. We believe that the consistent positive difference in permeability measured
by K & A Laboratories probably is the result of drying of the core-plugs of natural
sandstone. This inference is indicated by inspection of Figure 12, which shows
permeability measured by K & A Laboratories and the OSU laboratory plotted in
relation to porosity measured by K & A Laboratories. Data are shown as columns 6, 7
and 3, respectively, in Table 11.
10000
1000
.>>
I 100
CD
0>
CL-
10 100
P0rosty(%
KBANtrogen n OGUMtrogsn Natual Rock - ... Artificial Rock
Ram Rsrm
Figure 12. Porosity-permeability least-squares cross-plot. Data shown in Table 11.
Porosity measured by K&A Laboratories.
111
-------
Observe that permeability measured by K & A (black squares) and by OSU (white
squares) cluster, but permeability recorded by OSU is consistently the smaller.
A similar general relationship is observed from measurements of permeability of
artificial rock, although scatter of points tends to increase in rock with porosity less
than about 15 percent.
In granular porous rocks, an inverse relation between porosity and permeability
probably is the general case.
SELECTED REFERENCES
1. Sokal, R. R., and Rohlf, F. J., 1969, Biometry: W. H. Freeman and Company,
776 p.
2. Rohlf, F. J., and Sokal, R. R., 1969, Statistical tables: W. H. Freeman and
Company, 253 p.
112
-------
APPENDIX J
SIMULATED INJECTION SYSTEM. MUD-SETTLING PERMEABILITIES
AVERAGE PERMEABILITIES SELECTED ACROSS EIGHT DAYS
J1
-------
Table J1 Artificial reservoir permeability during settling conditions from 12/10/94 to 12/17/94
Test
Date
Average
Permeability
(md)
•Radial
Differential
Pressure Beginning
(psid) Time
Ending Test Duration
Time (Hours) (Minutes) (Seconds)
12/10/94
12/11/94
12/12/94
12/13/94
12/14/94
12/15/94
12/16/94
12/17/94
006236112
0.06606531
0.063946908
0.056416822
0054066705
0.035487514
0.027557203
0.03832137
1841585
18.200515
19.898344
20.905203
21.332364
35.148155
30.467328
31.730595
18:38:15
12:57:21
06:21:51
06:56:54
04:58:52
14:28:33
09:16-43
05:07:31
20-45:45
16:42:08
07:40:18
08.40:18
06:59:31
1646:31
11:10:10
0630:44
2
3
1
1
2
2
1
1
7
44
18
43
0
17
53
23
30
47
27
24
39
58
27
13
* Note: The pressure differential from 50 psid differential pressure transducer
J2
-------
APPENDIX K
MUD-SETTLING TESTS
DATA RECORDED FROM MUD-SETTLING TUBES
K1
-------
Date
Table K1 Mud-Settling Test 82092, Settling Tube 2
Mud
Time Date* Time RunTime Height
(in.)
Settlement
8/20/92
8/26/92
8/31/92
9/3/92
9/8/92
9/22/92
9/30/92
11/9/92
12/15/92
3/11/93
5/21/93
8/8/93
10/1/93
3/7/94
5/11/94
6/2/94
6/16/94
7/9/94
7/27/94
12/6/94
12/21/94
12:00
13:56
11:10
8:32
8:09
8:21
17:05
19:38
9:11
9:20
19:45
14:30
16:00
10:20
16:09
16:31
16:25
13:36
8:20
14:37
15:55
8/20/92 12:00
8/26/92 13:56
8/31/9211:10
9/3/92 8:32
9/8/92 8:09
9/22/92 821
9/30/92 17:05
11/9/9219:38
12/15/929:11
3/11/93920
5/21/93 19:45
8/8/93 14:30
10/1/93 16:00
3/7/94 10:20
5/11/9416:09
6/2/94 16:31
6/16/94 1625
7/9/94 13:36
7/27/94 8:20
12/6/94 14:37
12/21/94 15:55
0.0
6.1
11.0
13.9
18.8
32.8
41.2
81.3
116.9
202.9
274.3
353.1
4072
563.9
6292
6512
6652
688.1
705.8
838.1
853.2
66.88
66.00
66.50
6525
64.75
63.75
63.17
60.75
58.75
55.00
51.63
48.75
46.88
43.50
42.38
42.00
41.75
41.19
41.00
39.19
39.06
0.09
1.40
0.65
2.52
327
4.76
5.63
924
1223
17.83
22.87
27.17
29.96
35.01
36.69
3725
37.63
38.46
38.75
41.45
41.65
Date
Table K2 Mud-Settling Test 82092, Settling Tube 3
Time
Date «• Time
Run Time
Mud
Height
(in.)
Settlement
8/20/92
8/26/92
8/31/92
9/3/92
9/8/92
9/22/92
9/30/92
11/9/92
12/15/92
3/1/93
5/21/93
8/8/93
10/1/93
3/7/94
6/29/94
12/21/94
12:00
1:56
11:10
8:33
8:09
821
5:05
19:38
9:11
9:20
19:45
14:30
16:00
10:20
23:10
17:24
8/20/92 12:00
8/26/921:56
8/31/9211:10
9/3/92 8:33
9/8/92 8:09
9/22/92 8:21
9/30/92 5:05
11/9/9219:38
12/15/929:11
3/1/93 9:20
5/21/93 19:45
8/8/93 14:30
10/1/93 16:00
3/7/941020
6/29/9423:10
12/21/94 1724
0.0
5.6
11.0
13.9
18.8
32.8
40.7
81.3
116.9
192.9
274.3
353.1
4072
563.9
678.5
8532
45.19
40.88
39.69
39.13
38.50
36.94
36.13
33.75
32.81
30.31
29.00
27.81
2725
26.13
25.50
24.75
0.00
9.54
12.17
13.41
14.80
1825
20.04
25.31
27.39
32.92
35.82
38.45
39.70
42.19
43.57
4523
K2
-------
Table K3 Mud-Settling Test 3894, Settling Tube 1
Date
Time
Mud
Date* Time RunTime Height Settlement
(in.) (%)
3/8/94
3/21/94
3/25/94
3/31/94
4/12/94
4/25/94
5/11/94
6/2/94
6/16/94
7/19/94
12/6/94
12/21/94
13:57
8:41
14:55
15:37
15:38
14:40
16:07
16:25
16:14
13:36
14:35
14:50
3/8/94 13:57
3/21/94 8:41
3/25/94 14:55
3/31/94 15:37
4/12/94 15:38
4/25/94 14:40
5/11/9416:07
6/2/94 16:25
6/16/94 16:14
7/19/94 13:36
12/6/94 14:35
12/21/94 14:50
0.0
12.8
17.0
23.1
35.1
48.0
64.1
86.1
100.1
133.0
273.0
288.0
34.94
25.31
23.88
22.50
21.00
19.88
19.25
18.56
18.25
17.88
16.75
16.75
0.00
27.55
31.66
35.60
39.89
43.11
44.90
46.87
47.76
48.84
52.06
52.06
Date
Table K4 Mud-Settling Test 3894, Settling Tube 2
Time
Date + Time
Run Time
Mud
Height
(in.)
Settlement
3/8/94
3/21/94
3/25/94
3/31/94
4/12/94
4/25/94
5/11/94
6/2/94
6/16/94
7/19/94
12/6/94
12/21/94
13:55
8:40
14:55
15:37
15:38
14:40
16:07
16:26
16:14
13:40
14:35
14:50
3/8/94 13:55
3/21/94 8:40
3/25/94 14:55
3/31/94 15:37
4/12794 15:38
4/25/94 14:40
5/11/9416:07
6/2/94 16:26
6/16/94 16:14
7/19/94 13:40
12/6/94 14:35
12/21/94 14:50
0.0
12.8
17.0
23.1
35.1
48.0
64.1
86.1
100.1
133.0
273.0
288.0
34.25
23.99
22.56
21.31
19.88
18.94
18.31
17.81
17.56
17.25
16.75
16.75
0.00
29.96
34.12
37.77
41.97
45.80
47.58
49.02
49.73
50.63
52.06
52.06
K3
-------
Table K5 Mud-Settling Test 42894, Settling Tube 1
Date
Time
Date + Time
Run Time
Mud
Height
(in.)
Settlement
4/28/94
6/2/94
6/8/94
6/16/94
6/27/94
7/19/94
8/12/94
12/6/94
12/21/94
14:24
16:27
13:30
16:13
14:07
13:44
14:16
14:29
^^^— ^^•^^^•^^M^H
15:35
I 4/28/94 14:24
6/2/94 16:27
6/8/94 13:30
6/16/94 16:13
6/27/94 14:07
7/19/94 13:44
8/12/94 14:16
12/6/94 14:29
12/21/94 15:35
0.0
35.1
41.0
49.1
60.0
82.0
106.0
222.0
237.0
35.06
34.25
33.88
33.50
33.06
32.06
31.25
28.75
28.56
0.00
3.39
4.46
5.70
8.56
10.87
18.00
18.54
Table K6 Mud-Settling Test 42894, Settling Tube 2
Date
4/28/94
6/2/94
6/8/94
6/16/94
6/27/94
7/1Q/QX
»/l 9/lf4
8/12/94
12/6/94
12/21/94
Time
14:23
16:28
1:30
16:09
13:50
13:42
14:17
14:34
15:47
Date + Time
4/28/94 14:23
6/2/94 16:28
6/8/94 1:30
6/16/94 16:09
6/27/94 13:50
7/19/94 13:42
8/12/94 14:17
12/6/94 14:34
12/21/94 15:47
Run Time
0.0
35.1
40.5
49.1
60.0
82.0
106.0
222.0
237.1
Mud
Height
(in.)
34.75
34.44
34.13
33.75
33.19
32.94
32.44
30.25
30.13
Settlement
(%)
0.00
0.90
1.80
2.88
4.50
6.05
7.48
13.73
14.07
K4
-------
Table K7 Mud-Settling Test 5394, Settling Tube 1
Date
Time
Date + Time
Run Time
Mud
Height
(in.)
Settlement
5/3/94
6/2/94
6/16/94
7/19/94
8/12/94
12/6/94
12/21/94
16:00
16:30
16:12
13:42
14:17
14:36
15:50
5/3/94 16:00
6/2/94 16:30
6/16/94 16:12
7/19/94 13:42
8/12/94 14:17
12/6/94 14:36
12/21/9415:50
0.0
30.0
44.0
76.9
100.9
216.9
232.0
34.81
34.25
33.94
33.38
33.06
31.50
31.31
0.00
1.62
2.51
4.13
5.03
9.52
10.05
Date
Table K8 Mud-Settling Test 5394, Settling Tube 2
Time
Date + Time
Run Time
Mud
Height
(in.)
Settlement
5/3/94
6/2/94
6/16/94
7/1/94
7/19/94
8/12/94
12/6/94
12/21/94
16:00
16:30
16:11
9:50
13:44
14:15
14:27
15:02
5/3/94 16:00
6/2/94 16:30
6/16/9416:11
7/1/94 9:50
7/19/94 13:44
8/12/94 14:15
12/6/94 14:27
12/21/94 15:02
0.0
30.0
44.0
58.7
76.9
100.9
216.9
232.0
34.94
34.44
34.00
33.88
33.44
33.13
31.38
31.19
0.00
1.08
2.33
2.69
3.95
4.85
9.87
10.41
Table K9 Mud-Settling Test 51294, Settling Tube Filled From Top
Date
Time
Date + Time
Run Time
Mud
Height
(in.)
Settlement
5/12/94
6/2/94
6/8/94
6/16/94
6/27/94
7/19/94
7/22/94
8/12/94
12/6/94
12/21/94
16:15
1628
1:30
16:09
13:50
13:42
8:22
14:12
14:35
14:34
5/12/94 16:15
6/2/941628
6/8/941:30
6/16/94 16:09
6/27/94 13:50
7/19/94 13:42
7/22/94822
8/12/94 14:12
12/6/94 14:35
12/21/94 14:34
0.0
21.0
26.4
35.0
45.9
67.9
70.7
91.9
207.9
222.9
34.75
34.44
3425
33.75
33.19
32.13
31.88
31.50
30.19
30.19
0.00
0.90
1.44
2.88
4.50
7.72
8.44
9.52
1329
13.29
K5
-------
Table K10 Mud-Settling Test 51294, Settling Tube Filled From Bottom
Date
Time
Date + Time
Run Time
Mud
Height
(in.)
Settlement
5/12/94
6/2/94
6/16/94
7/1/94
7/19/94
8/12/94
12/6/94
12/21/94
16:12
16:29
16:11
10:18
13:45
14:15
14:23
14:34
5/12/94 16:12
6/2/94 16:29
6/16/9416:11
7/1/94 10:18
7/19/94 13:45
8/12/94 14:15
12/6/94 14:23
12/21/94 14:34
0.0
21.0
35.0
49.8
67.9
91.9
207.9
222.9
34.75
34.50
34.38
33.19
33.88
33.44
32.88
32.88
0.18
0.90
1.26
4.67
2.69
3.95
5.57
5.57
Table K11 Mud-Settling Test 51894, Settling Tube Filled From Top
Date
Time
Date + Time
Run Time
Mud
Height
(in.)
Settlement
5/18/94
6/2/94
6/8/94
6/18/94
6/27/94
7/19/94
7/27/94
8/14/94
12/6/94
12/21/94
16:20
16:27
13:30
16:06
14:10
13:39
8:21
14:18
14:31
15:42
5/18/94 16:20
6/2/94 16:27
6/8/94 13:30
6/18/94 16:06
6/27/94 14:10
7/19/94 13:39
7/27/94 8:21
8/14/94 14:18
12/6/94 14:31
12/21/94 15:42
0.0
15.0
20.9
31.0
39.9
61.9
69.7
87.9
201.9
217.0
34.75
33.44
32.88
32.44
31.75
30.50
30.13
29.50
27.75
27.63
0.00
3.77
5.38
6.65
8.63
10.95
12.04
13.87
18.98
19.34
Table K12 Mud-Settling Test 51894, Settling Tube Filled From Bottom
Date
Time
Date + Time
RunTime
Mud
Height
(in.)
Settlement
5/18/94
6/1/94
6/16/94
7/19/94
12/6/94
12/12/94
16:15
16:22
16:02
13:41
14:36
15:10
5/18/94 16:15
6/1/94 16:22
6/16/94 16:02
7/19/94 13:41
12/6/94 14:36
12/12/94 15:10
0.0
14.0
29.0
61.9
201.9
208.0
34.25
34.19
34.06
33.56
32.69
32.50
0.00
0.18
0.55
2.01
4.56
5.11
K6
-------
Table K13 Mud-Settling Test 52594, Settling Tube Filled From Top
Date
Time
Date + Time
Run Time
(days)
Mud
Height
(in.)
Settlement
5/25/94
6/2/94
6/8/94
6/16/94
6/29/94
7/19/94
7/27/94
8/12/94
12/6/94
12/21/94
14:30
16:32
13:30
16:09
14:59
13:42
13:23
14:17
14:25
15:33
5/25/94 14:30
6/2/94 16:32
6/8/94 13:30
6/16/94 16:09
6/29/94 14:59
7/19/94 13:42
7/27/94 13:23
8/12/94 14:17
12/6/94 14:25
12/21/94 15:33
0.0
8.1
14.0
22.1
35.0
55.0
63.0
79.0
195.0
210.0
34.50
33.94
33.25
32.50
31.31
29.50
29.00
28.19
26.31
26.06
0.00
1.63
3.62
5.80
9.24
14.49
15.94
18.30
23.73
24.46
Table K14 Mud-Settling Test 52594, Settling Tube Filled From Bottom
Date
Time
Date + Time
Run Time
(days)
Mud
Height
(in.)
Settlement
5/25/94
6/8/94
6/16/94
7/19/94
8/12/94
12/4/94
12/21/94
14:40
13:30
16:09
13:45
14:16
14:32
14:09
5/25/94 14:40
6/8/94 13:30
6/16/94 16:09
7/19/94 13:45
8/12/94 14:16
12/4/94 14:32
12/21/94 14:09
0.0
14.0
22.1
55.0
79.0
193.0
210.0
34.38
34.25
34.06
33.31
32.63
30.94
30.88
0.00
0.36
0.91
3.09
5.09
10.00
10.17
Table K15 Mud-Settling Test 6194, Settling Tube Filled From Top
Date
Time
Date + Time
Run Time
Mud
Height
(in.)
Settlement
6/1/94
7/18/94
7/27/94
8/12/94
12/6/94
12/21/94
20:50
13:37
8:20
14:18
14:34
1424
6/1/94 20:50
7/18/94 13:37
7/27/94 8:20
8/12/94 14:18
12/6/94 14:34
12/21/94 1424
0.0
46.7
55.5
71.7
187.7
202.7
34.75
33.56
33.31
32.50
2825
28.00
0.00
3.42
4.14
6.47
18.71
19.42
K7
-------
Table K16 Mud-Settling Test 6194, Settling Tube Filled From Bottom
Mud
Date Time Date + Time RunTime Height Settlement
(in.) (%)
6/1/94
7/19/94
8/12/94
12/6/94
12/21/94
20:53
13:41
14:18
14:32
14:30
6/1/94 20:53
7/19/94 13:41
8/12/94 14:18
12/6/94 14:32
12/21/94 14:30
0.0
47.7
71.7
187.7
202.7
34.75
34.13
33.75
32.88
32.75
0.00
1.78
2.88
5.38
5.76
Table K17 Mud-Settling Test 62294, Settling Tube Filled From Top
Date
Time
Date + Time
Run Time
Mud
Height
(in.)
Settlement
6/22/94
8/12/94
12/6/94
12/21/94
14:30
14:18
14:32
14:22
6/22/94 14:30
8/12/94 14:18
12/6/94 14:32
12/21/94 14:22
0.0
51.0
167.0
182.0
34.50
34.00
32.50
32.50
0.00
1.45
5.80
5.80
Table K18 Mud-Settling Test 62294, Settling Tube Filled From Bottom
Date
Time
Date + Time
Run Time
Mud
Height
(in.)
Settlement
6/22/94
12/6/94
12/21/94
10:50
14:37
14:30
6/22/94 10:50
12/6/94 14:37
12/21/94 14:30
0.0
167.2
182.2
34.56
34.25
34.25
0.00
0.72
0.72
Table K19 Mud-Settling Test 71894, Settling Tube Filled From Top
Date
Time
Date + Time
Run Time
Mud
Height
fm.)
Settlement
7/18/94
7/27/94
8/12/94
12/6/94
12/21/94
13:34
8:19
14:15
1420
14:14
7/18/94 13:34
7/27/94 8:19
8/12/94 14:15
12/6/94 1420
12/21/94 14:14
0.0
8.8
25.0
141.0
156.0
33.75
31.50
29.94
27.13
27.00
0.00
6.67
1129
19.61
20.00
K8
-------
Table K20 Mud-Settling Test 71894, Settling Tube Filled From Bottom
Mud
Date Time Date* Time RunTime Height Settlement
(in.) (%)
7/18/94
7/27/94
8/12/94
12/6/94
12/21/94
13:34
8:19
14:15
14:25
14:18
7/18/94 13:34
7/27/94 8:19
8/12/94 14:15
12/6/94 14:25
12/21/94 14:18
0.0
8.8
25.0
141.0
156.0
33.63
32.75
31.75
30.13
30.00
0.00
2.96
5.93
10.73
11.11
Table K21 Mud-Settling Test 111794, Settling Tube Filled From Bottom
Date
Time
Date + Time
RunTime
(days)
Mud
Height
(in.)
Settlement
11/17/94
12/3/94
12/6/94
12/21/94
12/29/94
18:40
8:40
14:29
13:53
10:59
11/17/9418:40
12/3/94 8:40
12/6/941429
12/21/94 13:53
12/29/94 10:59
0.0
15.6
18.8
18.2
22.9
34.25
29.00
28.25
25.94
25.10
0.00
15.33
17.52
24.26
26.72
Table K22 Mud-Settling Test 111894, Settling Tube 1
Date Time Date + Time
Mud
Run Time Height Settlement
(in.) (%)
11/18/94
12/3/94
12/6/94
12/21/94
22:50
8:40
1426
13:59
11/18/9422:50
12/3/94 8:40
12/6/94 1426
12/21/94 13:59
0.0
14.4
17.7
32.6
35.06
34.56
34.50
3425
0.00
1.43
1.60
2.31
Table K23 Mud-Settling Test 12294, Settling Tube Filled From Bottom
Mud
Date Time Date* Time RunTime Height Settlement
(in.) (%)
12/5/94
12/21/94
12/29/94
11:14
13:52
10:59
12/5/94 11:14
12/21/94 13:52
12/29/94 10:59
0.0
16.1
24.0
35.50
32.00
31.48
0.00
9.86
11.34
K9
-------
APPENDIX L
MUD PROPERTIES
M & P AND SIS TESTS
L1
-------
Table L1. Properties of mud used in M&P and SIS Tests.
M&P TEST
ID
MUD
WEIGHT
PPG
MARSH
FUNNEL
VISCOSITY,
SEC/QT
10 SECOND
GEL
STRENGTH,
LB/100FT2
10 MINUTE
GEL
STRENGTH,
LB/100 FT2
PLASTIC YIELD APPARENT
VISCOSITY POINT, VISCOSITY
12793
3894
42894
5394
51294
51894
52594
6194
6794
61494
62194
111694
9
9
9
9
9.05
9
8.98
9.03
8.99
9.02
9.02
ao2
36
36
35.61
36.19
36.21
36.52
36.59
36.6
36.56
36.12
36.12
35.59
5
5
4
6
4
3
3
3
3
4
5
6
15
9
12
13
15
12
11
13
17
22
18
15
11
7
11
10
10
11
8
7
6
8
9
8.6
12
9
11
10
10
8
10
7
7
8
8
9.9
\sr
17
11.5
16.5
15
15
15
13
10.5
9.5
12
13
13.5
SIS TEST
ID
AR-2
MUD
WEIGHT
PPG
MARSH
FUNNEL
VISCOSITY,
SEC/QT
10 SECOND
GEL
STRENGTH,
LB/100FT2
10 MINUTE
GEL
STRENGTH,
LB/100FT2
PLASTIC YIELD APPARENT
VISCOSITY POINT, VISCOSITY
CP LB/100FT2 CP
9.01
36.84
10
I 13.5 I
-------
APPENDIX M
ARTIFICIAL RESERVOIR 2
POROSITIES AND PERMEABILITIES OF CORE PLUGS
M1
-------
Table M1 1 Estimates of porosity, cores used in M&P tests Related information shown in Appendix H
Index to Tables,
Appendix H
Table H1
Table H2
M&P/Core ID
4. 16. A
4.1 1C
4.12.C
4.7 B
4.12.B
4.14.C
4.6.C
4.15.B
4.6.B
T4.3
T5.2
T5.3
T3.2
T4.2
T5.5
T5.4
T4.4
T4.5
WetWt
flm
DryWt
am
37.9
38.4
38.1
38.0
37.9
37.9
37.9
38.2
37.7
34.0
34.0
34.3
33.7
34.4
34.4
34.3
34.2
34.1
Vol
gm/cm'cm
18.49
18.46
18.55
18.53
18.56
18.57
18.60
16.61
18.56
18.23
18.25
18.23
18.24
18.35
18.39
18.36
18.15
18.15
WRhoB
cm'cm
DRhoB
gm/cm'cm
2.049
2.081
2.054
2.050
2.042
2.041
2.038
2.053
2.031
1.865
1.863
1.882
1.848
1.875
1.871
1.868
1884
1.879
Rhoma
gm/cm'cm
2.656
2.656
2.656
2.656
2.656
2.656
2.656
2.656
2.656
2.656
2.656
2.656
2.656
2.656
2.656
2.656
2.656
2.656
Phi Wet
%
Phi Dry
%
0.228
0.217
0.227
0228
0.231
0231
0233
0227
0.235
0.298
0.299
0292
0.304
0294
0.296
0.297
0.291
0293
N)
-------
Table M1 2 Estimates of porosity, cores used in M&P tests Related information shown in Appendix H
Index to Tables.
Appendix H
Table H3
Table H4
M&P/Core ID
7793:1 :1.180.A
1694:5:1.0.6
1594:1:1.90
1694:3:O.O.A
2 1294: 1:1.0. A
12894:2:1.0.6
1594:5:1.180
21894:2.0.0.A
1594:3:1.90
1594:2:1.180
12594:3:1.90.6
1694:5:1.90.A
7793:1 :1.270.A
1694:3.1. 180.A
12894:1:1.270,6
1594:3:1.270
11 894:3:1. 90.A
1694:5 1.180.A
WetWt
Qm
39.6
39.8
39.9
40.0
39.9
40.1
39.9
39.9
39.8
38.6
40.0
38.9
39.1
40.0
39.8
40.1
39.9
39.4
DryWt
flm
37.4
36.2
36.3
36.4
36.3
36.6
36.3
36.6
36.3
36.0
36.5
35.5
37.2
36.4
36.7
36.5
36.5
35.5
Vol
gm/cm'cm
1880
18.78
18.74
18.70
18.70
18.68
18.68
18.70
18.68
1863
18.73
18.35
18.64
18.69
18.75
18.67
18.72
18.64
WRhoB
cm*cm
2.106
2.119
2.129
2.139
2.134
2.147
2.136
2.134
2.131
2072
2.136
2.120
2.098
2.140
2.123
2.148
2.131
2.114
DRhoB
jm/cm*cm
1.989
1.928
1.937
1.947
1.941
1.959
1.943
1.957
1.943
1.932
1.949
1.935
1.996
1.948
1.957
1.955
1.950
1.905
Rhoma
gm/cm'cm
2.374
2.374
2.374
2.374
2.374
2.374
2.374
2.374
2.374
2.374
2.374
2.374
2.374
2374
2.374
2.374
2374
2374
Phi Wet
%
0242
0228
0217
0206
0.212
0.198
0210
0212
0215
0.282
0210
0.227
0252
0205
0224
0197
0214
0.234
Phi Dry
%
0.162
0.188
0184
0.180
0.182
0.175
0181
0.176
0.181
0.186
0.179
0.185
0159
0180
0.176
0176
0179
0198
-------
Table M1 3 Estimates of porosity, cores used in M&P tests Related information shown in Appendix H
Index to Tables,
Appendix H
Table H5
Table H6
M&P/Core ID
21294.2:1, 180.A
106944-1.270.8
032494:2.1.90.0
0324942:1.90.8
032494:2.1.180.6
032494.2: 1.270, A
021294:1:1.270.8
032494:2.1.180.0
031794 1:1.0.A
030894:1:1.0.6
021894:2:1.0.6
021294.5 1.270.A
032494 -1:1.0.0
032494.1:1.180.0
030894.1.1,90,6
0218941:1,0,8
021894:3.0,0,A
021294.5.1. 180.A
WetWt.
flm
39.3
400
38.8
38.6
393
39.1
40.1
394
39.7
399
405
40.2
39.7
39.7
39.7
40.0
39.9
404
DryWt.
am
37.0
367
36.2
36.3
36.2
362
370
36.3
37.2
36.9
37.3
37.0
36.7
36.6
36.7
37.1
37.1
373
Vol.
gm/cm*cm
18.88
18.65
18.50
18.50
18.49
1853
1872
18.47
18.97
1874
18.73
18.69
18.62
18.59
18.71
1875
18.87
1879
WRhoB
cm*cm
2.082
2145
2.097
2.086
2.125
2.110
2.142
2.133
2.093
2.129
2.162
2.151
2.132
2.136
2.122
2.133
2.114
2.150
DRhoB
gm/cm*cm
1.960
1968
1.957
1.962
1.958
1.954
1.976
1.965
1.961
1.969
1991
1.980
1.971
1969
1.962
1.979
1.966
1985
Rhoma
Qm/cm'cm
2374
2.374
2.374
2374
2.374
2.374
2.374
2374
2.374
2.374
2.374
2374
2.374
2374
2.374
2.374
2.374
2374
Phi Wet
%
0270
0200
0.252
0265
0221
0238
0203
0213
0257
0217
0182
0194
0.214
0210
0.225
0.212
0233
0195
Phi Dry
%
0174
0171
0.176
0.173
0175
0177
0167
0172
0174
0171
0161
0166
0.170
0171
0.174
0.167
0172
0164
-------
Table M1 4 Estimates of porosity, cores used in M&P tests. Related information shown in Appendix H
Index to Tables.
Appendix H
Table H7
Table HB
M&P/Core ID
0212942:1.270.6
021294.2:1.90.6
010694:4:1.90.8
032494.2:1.270.0
070793:1:0.0.8
02 1894: 5.0.0. A
021894.1:1.90.8
010694:2.1.0.8
032494.1:1.90.0
030894:1:1.270.0
021894:5:0.0.8
031794:1:1.90.0
021294:3:1.0.8
02 1894 3. 1.1 80. B
021294.3:1.90.8
030894:1:0.0.0
021894:5.1.90.8
021294:3:1.180.6
WetWt
Qm
40.2
40.4
403
39.6
38.9
40.1
39.8
40.1
39.5
• 39.9
40.6
41.5
40.5
40.1
40.5
40.3
40.6
40.4
DryWt
Qm
370
37.1
368
36.4
37.2
371
36.7
36.6
36.3
37.6
37.9
38.4
37.7
373
37.8
37.7
37.9
37.8
Vol
gm/cm*cm
18.70
1877
18.67
18.53
18.46
18.70
18.61
1868
18.53
18.67
1873
19.29
18.81
18.78
18.74
18.76
18.71
1884
WRhoB
cm'cm
2.150
2.152
2.159
2.137
2.107
2.144
2.139
2.147
2.132
2.137
2.168
2.151
2.153
2.135
2.161
2.148
2.170
2.144
DRhoB
gm/cm*cm
1.979
1.977
1.971
1964
2015
1.984
1972
1.959
1.959
2.014
2.023
1.991
2.004
1.986
2.017
2.010
2026
2.006
Rhoma
gm/cm'cm
2374
2.374
2.374
2374
2.374
2.374
2.374
2.374
2.374
2.374
2374
2.374
2.374
2374
2374
2.374
2374
2.374
Phi Wet
%
0195
0.192
0186
0208
0241
0201
0207
0.198
0214
0208
0177
0.193
0192
0210
0.183
0.197
0174
0201
Phi Dry
%
0.167
0167
0170
0.173
0151
0.164
0.169
0175
0.175
0152
0148
0161
0.156
0163
0150
0153
0.147
0155
Ui
-------
Table M1 5 Estimates of porosity, cores used in M&P tests Related information shown in Appendix H
Index to Tables.
Appendix H
Table H9
Table H10
M&P/Core ID
PC11A
PC14C
PC6B
PC14B
PC7C
PC10B
PC8B
PC12C
PC13B
9BHC
12AHC
6BHC
13BHC
14BHC
5BHC
7BHC
16BHC
15AHC
WetWt
am
41.1
40.6
40.3
40.9
41.0
40.5
40.7
40.7
40.4
41.5
41.2
40.7
41.7
41.8
42.2
41.5
41.0
41.4
DryWt
am
35.4
36.1
35.8
35.7
36.0
35.8
35.5
35.8
35.6
37.7
36.2
36.8
37.1
36.9
37.3
37.4
37.0
36.B
Vol
gm/cm*cm
18.37
18.70
1666
18.57
18.71
18.59
1861
18.60
18.69
18.76
17.99
18.70
18.51
18.22
1841
18.34
18.55
18.15
WRhoB
cm'cm
2.237
2.172
2160
2.203
2.192
2.179
2.187
2.188
2.162
2.212
2.290
2.177
2.253
2.294
2292
2.263
2.211
2.280
DRhoB
gm/cm*cm
1.927
1931
1.919
1.923
1.925
1.926
1.907
1.925
1.905
2.010
2.012
1.968
2.004
2.025
2.026
2.039
1.995
2027
Rhoma
flm/cm*cm
2656
2.656
2656
2656
2.656
2.656
2.656
2.656
2.656
2.656
2656
2.656
2.656
2.656
2.656
2.656
2.656
2656
Phi Wet
%
0339
0414
0428
0377
0389
0405
0.395
0.394
0.425
0.366
0283
0407
0.322
0.280
0282
0.312
0368
0293
Phi Dry
%
0275
0273
0278
0276
0.275
0275
0282
0275
0.283
0243
0242
0259
0.245
0238
0237
0.232
0249
0237
O)
-------
Table M1 6 Estimates of porosity, cores used in M&P tests Related information shown in Appendix H
Index to Tables,
Appendix H
Table H11
M&P/Core ID
AR-2.1.270.P
AR-2.1.0.A
AR-2.0.0.B
AR-2: 1,90,0
AR-2.0.0.0
AR-2.1.270.K
AR-2:1.90.M
AR-2.1.180.G
AR-2: 1,1 80.1
WetWt
qm
38.5
38.9
394
39.9
39.5
39.9
39.4
39.9
399
DryWt
flm
35,6
359
35.9
359
36.1
364
361
36.4
36.6
Vol
gm/cm*cm
1875
18.71
18.71
18.74
18.80
1882
18.78
1882
18.81
WRhoB
cm'cm
2.053
2.079
2.106
2.129
2.101
2.120
2098
2.120
2.121
DRhoB
gm/cm*cm
1.899
1.919
1.919
1.916
1.920
1.934
1.922
1.934
1946
Rhoma
gm/cm*cm
2.374
2.374
2.374
2.374
2.374
2.374
2.374
2.374
2374
Phi Wet
%
0304
0273
0243
0217
0248
0227
0251
0227
0225
Phi Dry
%
0200
0192
0192
0193
0191
0185
0190
0.185
0180
-------
Table M2 Porosities and Permeabilities, Core Plugs, Artificial Reservoir 2.
Six lifts, 0.95-Halliburton mixture.
'SAMPLE #
AR-2: O.O.A
AR-2: 1.0.A
AR-2: 1.90.A
AR-2: 1.1 80. A
AR-2: 1.270.A
AR-2: 0.0, B
AR-2: 1.0.B
AR-2. 1,90,6
AR-2. 1.180.B
AR-2: 1 .270,8
AR-2: O.O.C
AR-2:1.0.C
AR-2: 1.90.C
AR-2. 1.180.C
AR-2:1.270.C
AR-2: 0,0.0
AR-2:1.0.D
AR-2 1.90.D
AR-2 1 .180.0
AR-2: 1.270.D
AR-2: O.O.E
AR-2. 1.0.E
AR-2: 1.90.E
AR-2. 1,1 80.E
AR-2-1.270.E
AR-2: O.O.F
AR-2: 1.0.F
AR-2. 1.90.F
AR-2. 1.180.F
AR-2: 1.270.F
DENSITY
GM/CC
1.924
1.919
1.922
1.923
1.925
1.919
1.926
1.921
1.941
1.914
1.928
1.919
1.935
1.927
1.928
1.926
1.933
1.915
1.939
1.926
1.942
1.915
1.924
1.930
1.917
1.946
1.944
1.915
1.927
1.934
AVERAGE
DENSITY
GM/CC
1.923
1.924
1.928
1.928
1.926
1.933
N2-PERM
md
2213.024
2245.963
2267.190
2121.375
2517.009
1997.547
2175.350
1981.221
1847.961
1725.803
2177.321
2112.388
2179.876
2086.349
2134.994
1677.607
1654.531
1904.783
1434.739
1436.831
1665.727
2542.986
2184.663
1949.464
2032.248
1023.049
1031.369
1448.951
1359.096
690.429
AVERAGE
PERMEABILITY
(1-5).(6-10)
(1-10)
md
2272.912
1945.577
2138.186
1621.698
2075.018
1110.579
SAMPLE
POROSITY
%
18714
18.944
18.810
18.778
18.710
18.938
18.653
18.846
18.035
19.175
18.550
18.931
18.260
18.610
18.563
18.658
18.373
19.095
18.088
18.656
17.968
19.102
18.727
18.478
19.047
17.817
17.877
19.095
18.603
18.293
AVERAGE
POROSITY
%
18.791
18.729
18.583
18.574
18.664
18.337
MS
-------
Table M2 (continued) Porosities and Permeabilities, Core Plugs, Artificial
Reservoir. Six lifts, 0.95-Halliburton mixture.
AR-2 O.O.G
AR-2 1.0.G
'AR-2 1.90.G
AR-2. 1.180.G
AR-2: 1.270.G
AR-2: O.O.H
AR-2- 1.0.H
AR-2- 1.90.H
AR-2. 1.180.H
AR-2: 1.270.H
AR-2: O.O.I
AR-2: 1.0.1
AR-2: 1.90.1
AR-2. 1.180,1
AR-2: 1.270.1
AR-2: O.O.J
AR-2: 1.0.J
AR-2: 1.90.J
AR-2: 1.180.J
AR-2: 1.270.J
AR-2: O.O.K
AR-2: 1.0.K
AR-2: 1.90.K
AR-2- 1.180.K
AR-2: 1.270.K
AR-2. O.O.L
AR-2: 1.0.L
AR-2: 1.90.L
AR-2: 1.180.L
AR-2. 1.270.L
1.936
1.947
1.930
1.934
1.928
1.934
1.935
1.927
1.934
1.944
1.934
1.933
1.919
1.946
1.930
1924
1.914
1.924
1.927
1.917
1.941
1.923
1.921
1.934
1.934
1.929
1.929
1.922
1.923
1.927
1.935
1.935
1.932
1.921
1.931
1.926
1350.678
1290.254
968.975
1256.277
1592.913
870.873
744.839
957.987
971.624
830.952
1084.595
877.431
1175.172
919.879
978.368
2276.959
2729.017
2063.751
2110.928
2474.730
1114.250
1269.817
1516.387
1353.515
1578.130
1166.921
1119.171
1443.117
1000.376
1340.897
1291.820
-
875.255
1007.089
2331.077
1366.420
1214.097
18.207
17.750
18471
18.319
18.577
18.313
18.266
18.596
18.313
17.878
18.300
18.359
18.954
17.811
18471
18.749
19.158
18.751
18.603
19.034
18.028
18.763
18.856
18.313
18.313
18.538
18.531
18.822
18.780
18.590
18.265
18.273
18.379
18.859
18.454
18.652
M9
-------
Table M2 (continued) Porosities and Permeabilities, Core Plugs, Artificial
Reservoir. Six lifts. 0.95-Halliburton mixture.
AR-2: O.O.M
AR-2: 1.0.M
AR-2: 1.90.M
AR-2: 1.180.M
AR-2: 1.270.M
AR-2: O.O.N
AR-2: 1.0.N
AR-2: 1.90.N
AR-2: 1.180.N
AR-2: 1.270.N
AR-2: O.O.O
AR-2: 1.0.O
AR-2: 1.90.O
AR-2: 1.180.O
AR-2: 1.270.O
AR-2: O.O.P
AR-2: 1.0.P
AR-2: 1.90.P
AR-2: 1.180.P
AR-2: 1.270.P
AR-2: O.O.Q
AR-2: 1.0.Q
AR-2: 1.90.Q
AR-2: 1.180.Q
AR-2: 1.270.Q
1.926
1.922
1.922
1.931
1.924
1.918
1.921
1.921
1.925
1.920
1.920
1.933
1.918
1.931
1.926
1.894
1.917
1.873
1.901
1.898
1.893
1.902
1.882
1.893
1.893
1.925
1.921
1.926
1.897
1.893
1364.853
1411.458
1280.043
1207.228
1163.201
2134.758
2030.286
2078.846
2060.121
2147.403
1803.265
1697.697
2317.859
1561.046
1576.391
2971.427
1586.226
-51.346
-51.601
2719.313
3008.470
2998.153
-51.613
2495.354
2993.057
1285.357
2090.283
1791.252
2425.655
2873.759
18643
18.809
18.815
18432
18.749
18.988
18856
18.874
18.704
18.920
18.881
18.372
18.991
18.432
18.636
19.998
19.029
20.878
19.715
19.816
20.047
19.663
20.493
20.055
20.043
18.690
18.868
18.662
19.887
20.060
GRAND AVERAGE POROSITY= | 18.749 |
M10
-------
APPENDIX N
COMPUTER SOFTWARE
SOFTWARE HIGHLIGHTS
Software programs were written in Microsoft Quickbasic version 4.5. Several
programs were developed for the different program requirements. The programs
developed for this project were:
DOWN-HOLE AND TOP-SIDE DATA ACQUISITION
FINALDH1.BAS:-
Program for operation and data collection of down-hole and top-side sensors.
This program continually cycles through the sensors and provides real-time monitor
display of all twenty seven sensors in calibrated engineering units and saves raw data
onto disk at a selected interval. The selected interval to save data can be any time in
seconds.
A delay routine was incorporated which waits until the end of sampling of all
sensors in a cycle before saving data. This insures continuity of when data are saved,
instead of random intervals that may be in the middle of a cycle.
Another feature provides a display of the amount of disk space used on the
recording data drive, so the operator can tell when to change out the data disk during
long-term data collection.
Two data files are created, for top-side data and down-hole data. The files are
closed at midnight and a new file is opened with a numerical value in the data file
name incremented by one in each file.
FLMTRCAL.BAS:-
This program is used to collect data in the calibration of the flowmeter test
stand. Data recorded are scale data (through an RS-232 serial port) for weighing
discharge water from the test stand, water pressure into the stand, and temperature
N1
-------
and position of each Temposonics instrument. These included the BPC, SIS, and
vertical water column Time was also saved for each cycle of data collected.
PERMTEST1.BAS:-
Program for collecting permeability test data. Sampled Salt Water Injection
pressure (SW1NJ), outer-diameter reservoir pressure (OD RES), 50 PSID pressure
temperature and position of vertical column, BPC, and SIS Temposonics instruments
on the flowmeter stand, as well as time for each data cycle.
M&P DATA ACQUISITION
MUDTEST.BAS:-
Used for general operation of the M&P Data Acquisition system. This program
provided a menu to weigh a water sample using an AND scale with an RS232 serial
port, or to acquire data from the M&P test stand. Sensors polled included nine flow
detectors for detecting drips, positions of three valves, a thermocouple measuring
temperature inside the M&P stand, three temperature monitors at each valve position
500 psig and 50 psig pressure transducer, and a small Ohaus scale.
Data collected for the nine-flow detectors were sampled at ten times the rate for
the other analog sensors, approximately 10 times per second. This was necessary in
order to detect a dropping drip. All nine detectors and the three valve positions were
saved as one HEX value. This helped to reduce file size and maximize speed in
saving data.
Data were saved as three files; '.ana' for analog; '.dig' for digital or HEX data
and .sea for scale data from the AND scale, along with a time stamp for each data
collection.
An alarm feature was added which gave a visual and audible alarm if either
pressure reached 80 percent of its rated sensor.
DELTA3T.BAS:-
A smoothing routine which converts raw digital data (.dig) files from the flow-
detector sensors and converts them to usable form. Due to the high sampling rate of
! fl°w,?®iectors.tne d'9'tal data were saved as a HEX number. This program strips
out the HEX value corresponding to the sensor number, converts it to a binary value
and saves that value to -a new file, along with the start and stop time of the drip. The
program then takes the next sensor number and repeats the operation. If the HEX
N2
-------
value for that sensor is zero (if no drip is detected), data are not recorded, thus
reducing the file size.
AVG1.BAS:-
Program to take twenty samples of raw analog data, calculate a running
average and save averaged data to a new file. This reduced the analog data by a
factor of twenty to one.
AVG1-H.BAS:-
Modified version of AVG1 but uses 40 data points for averaging. This program
is used on very large files. File output name is the same as the input file name except
the file extension is '.RNA'
Example of file size reduction using AVG1 and AVG1_H.
Original file size: 2,668,240 bytes
Using AVG1: 455,222 bytes
Using AVG1_H 77,458 bytes
V-AVG1.DOC:-
This routine is used after the data files have been searched to find the start
and stop time for a given digital output variable, which are inputs to this program.
Since only a single analog value, the average value, is used in data reduction, then
the time period for which it is averaged must match the digital data. This program
determines the average value of the variables from the 500 psig and 50 psig pressure
transducers, mud-temperature sensor and the three M&P sub-assembly temperature
sensors. The files to be used with this software is either a .ANA or .RNS data file.
The output file has the same name as the input file except it has an extension of .avg.
All programs were compiled into executable programs (.EXE) for operation in a
stand-alone environment
N3
-------
APPENDIX N, ATTACHMENT 1, PROGRAM: FINALDH1.BAS
8P^IK^K^SFS?F1FLE?PEDS?'FILE™PDI RLE™PTI)
MALDH1 BAS W HOLLOWAY 12/09/94
OSU EROL DATA ACQUISITION PROGRAM-
viEWPRINT3TO25 CLS
LOCATE 6. 5 PRINT I/O PORT BASE ADDRESS (SW> IS SET TO HEX 220"
LOCATE 4. 33 PRINT -SETUP ROUTINE'
CALLSAypSKISH. P» FD*. DRVS FILETMPDS. FILETMPTS) MODULE TO SAVE DATA
£K°SAVE FLAG PK=TMER DELAY FOR SAVE DATA. FD*=DAY NUMBER FLAG
•DRV$=DRIVE, FILETMPDS=TEMP DOWNHOLE DATA FILE. FILETMPTS=TEMP TOPSIDE DATA FILE
CLS
OLDTMES = TIMES 'INITIALIZE FLAG TO CURRENT TIME FOR NEW FILE
DEL% = 0 -SET DELAY FLAG FOR TIMER/CH=99 SAVE DATA TO OFF
LOCATE 4 1 PRINT-SAVE ON DRV I DRVS
END IF
IF S% = 1 THEN
ON TMER(P%) GOSUB DELAY DELAY TOMER INTERVAL FOR SAVE
END IF
IFS* = OTHEN
LOCATE 4. 1 PRINT -SAVE OFF-
DO
WHILE INKEYS o CHRS(27) "LOOP WHILE -ESC1 KEY NOT PRESSED
• ====» INITIALIZE DRIVER USING FUNCTION 0
DMDAT%(4) ARY1%(100).ARY2K(100)-CREATE ARRAYS
PORTK = &H220 -SET I/O PORT BASE ADDRESS
DAT%(0) = PORT* •GETK>PORTBASEADSRKS
ERS e o 'INITIAL ERROR VALUE
FUN%*0 -INITIAL FUNCTION VALUE
CALL PCL711(FUNS SEGDAT%(0) SEGARY1%(0) SEGARY24M01 ERV1
IF ER% «» 0 THEN PRINT "DRIVER WITOL^TKW FAIl.EDnFWC«rSTOP
1 SET PCL-711 INPUT CHANNEL INPUT CHANNEL ON DATA ACQ CARD
READ CH -READ DATA CHANNEL
IF CH >= 24 AND CH <= 29 THEN
ELSElFCH = 71THEN
ELSETFCH = 72THEN
ELSE~R% = 0
END IF
DAT%(0) = RS
FUN«-1
CALL PCL711 (FUNK SEG DAT%(0) SEGARY1%<0) SEG ARY2%(0). ER%)
IF ERS o 0 THEN PRINT "SET SCAN CHANNEL FAILED'" STOP
LOCATE 24 1 0
" • " OBTAIN DATE FOR THIS SAMPLE
LOCATE 3.6O- PRINT "DATE ~- DATES
• SELECT CHANNEL ON SIG COND TO MONITOR USING FUNC 21
21
DATK(O) = CH
IF CH = 99 AND DELS = 1 AND S% = 1 THEN
GOSUB GETTIME
RESTORE
DELS •= 0
ELSEIF CH = 99 THEN
RESTORE
END IF
CALL PCL71KFUNW SEG DATK(O) SEG ARYIS(O). SEG ARY2%<0). ERS)
IF ER% <> 0 THEN PRINT "SELECT CHANNEL TO MONITOR FAILED (FUN21)" STOP
=> PERFORM A/D CONVERSION USING FUNC 3
N4
-------
DATM(O) = 0 'ANALOG CHANNEL ON PCL-71 1
FUNK = 3
FOR O = 1 TO 5000 NEXT O DELAY LOOP TO ALLOW Art) TO SETTLE
CALLPCL711(FUNH SEG DATK(O) SEGARY1K(0) SEGARY2%(0) ERH)
IF ERK «> 0 THEN PRINT 'A/D CONVERSION FAILED" STOP
LOCATE 12 37 PRINT "A/DCH - RK 'ANALOG CHANNEL NO
LOCATE 11 40 PRINT USING -CH M- CM 'CHANNEL BEING SAMPLED
DATK(O) = OATK(0) * 2048
LOCATE 10. 38 PRINT USING T)ATA.MM»- DATK(O) 'DIGITAL DATA VALUE (0-4095)
•===> CONVERT ANALOG SENSOR INPUT DATA INTO USABLE FORM
IF CH = 0 THEN CHO = -816 816 • 995902 • DATW(O) - 000016 • DATK(O) * 2 'IF CHO < 0 THEN CHO = 0 'ICS
IF CH = 0 THEN DPO = DATK(O) 'SETS DP=DIGITAL VALUE
IF CH = 1 THEN CHI = -765 038 » 938057 • DAT*<0) - 0000032 • DAT%(0) " 2 'IF CHI < 0 THEN CHI = OICS
IF CH = 1 THEN DPI = DATS(O)
IF CH = 2 THEN CH2 = -263 246 • 321501 • DATK(O) - 000003 * DATK(O) • 2 'IF CH2 < 0 THEN CH2 = (T1000PSI CASING ICS
IF CH = 2 THEN DP2 - DATH(O)
IF CH = 3 THEN CHS = -fl10 29 • 1 00392 • DATS(O) - 000017 • DATV(O) • 2 'IF CHS < 0 THEN CHS = 0-3000PSI FLMTR STAND
IF CH = 3 THEN DP3 = DATS(O)
IFCH°4THENCH4».262S94* 322035 • DATH(0) - 000003 • DATK{0) • 2 'IF CH4 < 0 THEN CH4 = OnOOOPSI OD RES
IF CH = 4 THEN DP4 = DATK(O)
IFpCH =_5 THENCH5 =_-7 49852 * 008493 • DATW(O) - 0000001 • DAT%(0) " 2 'IF CHS < 0 THEN CHS = ffSENSO
IF CH = 8 THEN CHS = (DATK(O) / 12 3664) * 4 5T1 TEMPERATURE DATA
IF CH = 9 THEN CH9 = (DAT%(0) / 12 3664) • 5 5T2
IF CH = 10 THEN CH10 = (DATW(0) / 12 3664) * 4 3T3
IF CH = 1 1 THEN CH1 1 = (DATK(0) / 12.3664) « 5T4
IF CH = 12 THEN CH12 = (DAT%(0) / 12 3664) • 4 6T5
IF CH = 13 THEN CH13 = (DATO(O) / 12 3664) • 4 6T6
IF CH = 14 THEN CH14 = (DAT%(0) / 12 3664) * OT7
IF CH = 15 THEN CH15 =
-------
CLS
LOOP
DELAY
RETURN =
GETTME
SELECT CASE E* """ " ONTINUE OR Err> - ES
CASEHC--C-
CASE -x- •*-
IF S% = 1 THEN
G?iuBECLSOSFILPE"MT "PLEASE WUT ^"^ DATA FILES ARE 8EING CLOSED-
END IF
CLS END
END SELECT
> SAVE ANALOG DATA TO DISK
'SET DEL*Y FLAG °N
DTS = DATES
NEWHRSS = LE
ENDIF
{•OCATE 21. 40 PRINT TWE LAST SAVED - TIMES
"*1™* INTERVAL": •"* "SECONDS'
FILESPECS
END IF
LOCATE 4. 16 PRINT USING IS MT. SEEK
LOCATE 4. 21 PRINT •% FULL-
END IF
LOCATE 4. 35 PRINT USING -DAY *T FDK
FILETOPS = FILETMPTS * FDS
-OOWNHOLE DATA FILE
TOPSIDE DATA FILE
. USING TM»«.-CH14 CH15 CH16 CH17
DP29- ^
CLOSE
RETURN
NEWFILE
RETURN™* * 1 'INCREMENT DAY F|LE NUMBER BY ONE
CLOSFILE
OPEN FILEDWNS FOR APPEND AS »1
OPEN FILETOPS FOR APPEND AS t2
PRINT *1 -L1T.--L2T -;-L3T.- 'L4T • "IST "LET
PR!MT % ' DT|P * " UDP'* " L3DP>' " L4OP-" " L50P>": "
XSGT."VERT-:-BPCT.-:-SIST '
"fpd'- -C|,f P"v|«riTg
PRINT «2 DTS ....
RETURN CL°SE
•DATA CHANNEL INPUT SAMPLED
DATA 8910111213 0.24.25 25.27 28 1
DATA 14 15.16 17.5.3 0.2 4 72 71 48.40.29.32.99
SUBSAVDSK(S% ^% FD*. DRVS FILETMPDJ, FILETMPTS)
LOCATE 10 5 INPUT "SAVE DATA TO DISK »Y*N) - SAVS
^ •" " ™E '
- -W50P." -D1000.-
WEND
!r f*J5 = 3J."2R ^V* • •"•THSN S% = & EXIT SUB
IF SAVS = -Y-OR SAVS = V THEN SH = 1 ELSE S% = 0
LOCATE 12 5 INPUT -WHICH DRIVE (A.B CD)' DRVS
WHILE DRVS <>-A- AND DRVS <> "V AND DRVS « tT AND DRVS <> T>-
LOCATE 12 28 INPUT DRVS
WEND
LO<;AZE eU INPUT "M** FILE "AME
-------
WEND
LOCATE 16 S PRINT-PERIOD OF TIME BETWEEN SAVING DATA (IN SECONDS)- P%
LOCATE 16 S3 INPUT PW
LOCATE IB. 5 PRINT "DATA WILL BE SAVED TO DRIVE • " DRVS. • • AS FILE - DFNS » • • FD%
LOCATE 19. 5 PRINT 'AT AN INTERVAL OF ' P» - SECONDS-
LOCATE 21 5 PRINT -ONTINUE OR ETURN TO SETUP ' CONS
LOCATE 21 37 INPUT CONS
WEND
FILETMPDS = DRVS » • \" » DFNS » • D- 'DOWNHOLE DATA FILE
^ILETMPTS = DRVS - "V . DFNS * ' r TOPSIDE DATA FILE
END SUB
N7
-------
APPENDIX N, ATTACHMENT 2, PROGRAM: FLMTRCAL.BAS
DECLARE SUB SAVDSK (SS PS FILEDWNS FILETOPS MSGS)
COLOR 7.1
'-' r> FLMTRCAL BAS W HOLLOWAY 915196
•===> FLOW METER CALIBRATION PROGRAM
CLS
PRINT • OSU EROL DATA ACQUISITION PROGRAM-
PRINT- DEVELOPED FOR EPA DOWNHOLE PROJECT
VIEW PRINT 3 TO 25 CLS
LOCATE 6 5 PRINT I/O PORT BASE ADDRESS (SW) IS SET TO HEX 220"
LOCATE 4 33 PRINT "SETUP ROUTINE-
CALL SAVDSKfSS PS FILEOWNS FILETOPS. MSGS)
CLS
IF SW = 1 THEN
ON TMER(PK) GOSUB GETTME
TIMER ON
END IF
OPEN TOM1.2400.N.8.1.LF- FOR RANDOM AS (3' SCALE
DO
WHILE INKEYS o CHRS(27)
' > INmAUZE DRIVER USING FUNCTION 0
•CLS
DIM DAT*<4). ARY1S(100). ARY2S( 100)'CREATE ARRAYS
PORT% = &H220 'SET I/O PORT BASE ADDRESS
DATSfO) = PORTS 'GET I/O PORT BASE ADDRESS
ER% = 0 'INITIAL ERROR VALUE
FUNS = 0 -INITIAL FUNCTION VALUE
CALL PCL71KFUNK SEG DATH(0). SEG ARY1S(0). SEG ARY2%(0). ER%)
IF ERS <> 0 THEN PRINT "DRIVER INITIALIZATION FAILED' (FUNCSOr STOP
> SET PCL-711 INPUT CHANNEL
FUNS = 1
•READ CH -READ DATA CHANNEL
•IF CH = 71 THEN R% = 1 ELSE IF CH = 72 THEN R% = 2 ELSE R% = 0
OAT%(0) » 0
CALLPCL711(FUN% SEG DATS(O) SEG ARY1K(0). SEG ARY2%(0). ERS)
IF EPS <> 0 THEN PRINT "SET SCAN CHANNEL FAILED' STOP-
LOCATE 24 1 0
> OBTAIN DATE AND TIME FOR THIS SAMPLE
LOCATE 3 GO PRINT "DATE ". DTS
LOCATE 4 60 PRINT TIME '.TIMES
• SELECT CHANNEL ON SIG COND TO MONITOR USING FUNC 21
FUNK = 21
READ CH • READ SIG COND CHANNEL FROM DATA
DATM(O) = CK
IF CH = 99 THEN RESTORE
CALL PCL711(FUNK. SEG DAT%(0) SEGARY1%(0) SEG ARYZ%(0). ER%)
IF ERK <> 0 THEN PRINT -SELECT CHANNEL TO MONITOR FAILED (FUN21T STOP
= > PERFORM M> CONVERSION USING FUNC 3
FUNS = 3
DATS(O) = 0 -ANALOG CHANNEL ON PCL-711
FOR 0 = 1 TO 5000 NEXT 0 'DELAY LOOP TO ALLOW A/D TO SETTLE
CALLPCL711(FUN% SEG DATS(O) SEG ARYIS(O). SEG ARYZS(0) ERS)
IF ERS <> 0 THEN PRINT 'A/D CONVERSION FAILED1" STOP
IF SS = 1 THEN LOCATE 4 1 PRINT "SAVE ON" ELSE PRINT "SAVE OFF"
LOCATE6 1 PRINT CH
=> CONVERT ANALOG SENSOR INPUT DATA INTO USABLE FORM
DATS(O) = DATS(O) «• 204B
N8
-------
LOCATES 1 PRINTUSINGTHHttr. DATK(0)
If CH o 3 THEN CHS = ((950 / 3087) • DAT%(0» - 252 96 IF CH3 < 0 THEN CHS = (TICS
IF CH = 3 THEN DP = DAT%<0)
IF CH = 15 THEN CH15 = (DATH(O) /12 3664)» 5 STB
IF CH = 16 THEN CH16 = (DATK(0) / 12 3664) » 3 4T9
IF CH = 17 THEN CH17 = (DATH(O) / 12 3664) . 2 7T10
IF CH = 32 THEN CH32 = DATS(O) • (5 / 2048) TEMPO 1
IF CH = 40 THEN CH40 = DAT%(0) • (5 / 2O46) TEMPO 2
IF CH = 48 THEN CH48 = DATK(O) • (5 / 2048) TEMPO 3
- DISPLAY TOP SIDE SENSOR DATA
LOCATES 45 PRINT TOP LOC SENSOR READING'
•LOCATE 6 48 PRINT 1-
•LOCATE 6 54 PRINT USING • DPF-1 MM 9 PSI". CH71
•LOCATE? 54 PRINT USING "DPF-2 MM • PSr CH72
•LOCATE 6 54 PRINT USING " IP-7 MM* * PSP CH2
LOCATE 9. 54 PRINT USING " IP-6 MM • PSf. CH3
10CATE 10. 54 PRINT USING • IP-9 MM * PSI". CH4
'LOCATE 11. 54 PRINT USING " DP-7 MM * PSr CH29
•LOCATE 12 54 PRINT USING " DP-8 MM 9 PS P. CHS
•LOCATE 13 54 PRINT USING • T-7 M» • 0F-. CH14
LOCATE 14. 54 PRINT USING "T-8 9999 aF": CH15
LOCATE 15. 54 PRINT USING• T-9 9999ef-. CH16
LOCATE 16. 54 PRINT USING "T-10 M* * 0F-; CH17
LOCATE 21. 54 PRINT USING TMPO-1 99 999 VOLTS" CH32
LOCATE 22. 54 PRINT USING TMPO-2 M 999 VOLTS' CH40
LOCATE 23. 54 PRINT USING TMPO-3 MM* VOLTS'. CH48
' SCALE SETUP WITH SCALE OFF PRESS "RE-ZERO" WTTH "TOT TO BRING UP
• PARAMETER SETTINGS PRESS -PRINT TO CHANGE TO "GROUP B SETTINGS-
' PRESS -RE-ZERO' TO MOVE CURSOR UNDER NUMBER TO CHANGE
1 GROUP B SETTING SHOULD BE 603022 3 - COMMAND MODE. 0 • 2400 BAUD
• 2 - NO PARITY. 2 - 8 BrT/1 STOP BIT
'WEIGH SAMPLES USING LARGE SCALE
• FORX=1TO5000 NEXTX
PRINT *3 -OT
FORX = 1T07500 NEXTX
IFNOTEOF(3)THEN
SC$ = MPUTS(LOC(3). *3) FOR E = 1 TO 10- NEXT E
END IF
SCS'MIDKSCS.4 9) SC = VAUSCS)
LOCATE 10. 5 PRINT USING "SCALE = MM* * g -. SC
WEND
•===> CLOSE AND EXIT
CLS
LOCATE 10. 5 INPUT • ONTINUE OR EfT» - ES
SELECT CASE ES
CASE TC". -e-
CLS
CASETT V
IF S% = 1 THEN
LOCATE 1510 PRINT "PLEASE WAIT WHILE DATA FILES ARE BEING CLOSED"
•OPEN FILEDWNS FOR APPEND AS *1
OPEN FILETOPS FOR APPEND AS 92
•PRINT *1 "CH8 1"CH9 " "CHO "CH24." - CH10." CH25 ." "CH11 "
•PRINT »1 "CH26." "CH12 ": "CH27 .". "CH13 .". -CH28 .- "CHI "TIME*
•PRINT «1 DATES
PRINT*2 "SCA -.-CHS.'-CHIS "
PRINT *2 " CH16 " - CH17 ."• " CH32 .". " CH40." " CH4B 1 "TIME ~
PRINT 92 DATES
PRINT 92 ••
PRINT 02. MSGS
CLOSE
FOR X e 1 TO 10000 NEXT X
END IF
CLS END
END SELECT
CLS
LOOP
•»=»«»»> SAVE ANALOG DATA TO DISK
N9
-------
GETTIME
IF S« •> 1 THEN
OPEN FILETOPS FOR APPEND AS »2
PRINT n USING-WMM0- SC
PRINT n USING TKMM ." OP
PRINT 02. USING •*•*» * - CHI 5
PRINT 82 USING-WWW «- CH16 CH17
PRINT n USING •*»••»- CH32. CH40 CH48
PRINT*2 '".TIMES
CLOSE *2
END IF
RETURN
DATA 3 15 16 17.32 40.48.99
SUBSAVDSKfS* P* FILEDWNS FILETOPS MSGS)
LOCATE 10 15 INPUT "MAKE SURE SCALE IS ON-. ONS
CLS
WHILE CONS <> T"
CLOSE
LOCATE 7. 5 tNPUT -<2>ERO SCALE (Y/N)". ZS
IF ZS = V OR ZS = -V THEN
CLS
LOCATE 6 1 PRINT "PLEASE WATT FOR SCALE TO REZERO"
OPEN -COM1 2400.N.8 1.LF* FOR RANDOM AS *3
FOR D ° 1 TO 3000 NEXTD
PRINT *3 "R"
FOR X = 1 TO 20000 NEXTX
CLS
LOCATES. 1 PRINT "SCALE HAS BEEN REZEROED-
CLOSE *3
END IF
LOCATE 10. S INPUT -SAVE DATA TO DISK (Y/N) -. SAVS
WHILE SAVS o -NT AMD SAVS o "n" AND SAVS » "TAND SAVS o V
LOCATE 10 29 INPUT SAVS
WEND
IF SAVS = tf OR SAVS = ti- THEN S% « a EXIT SUB
IF SAVS = -Y-OR SAVS = V THEN S% n 1 ELSE SK = 0
LOCATE 12. S INPUT "WHICH DRIVE (A.B.C.O ) - DRVS
WHILE DRVS <> -A" AND DRVS o "B'AND DRVS « TT AND DRVS <> "D"
LOCATE 12.28 INPUT DRVS
WEND
LOCATE 14 5 INPUT -WHAT DATA FILE NAME (DO NOT TYPE EXTENSION) - DFNS
WHILE DFNS = ~
LOCATE 14.49 INPUT DFNS
WEND
LOCATE 16 5 PRINT "PERIOD OF TIME BETWEEN SAVING DATA (IN SECONDS)' P%
LOCATE 16 53 INPUT P%
LOCATE 18.5 PRINT "DATA WILL BE SAVED TO DRIVE " DRVS "AS FILE "• DFNS
LOCATE 19. 5 PRINT "AT AN INTERVAL OF - PH. • SECONDS"
IF SH - 1 THEN
LOCATE 20. 5 PRINT "ENTER COMMENTS FOR THIS TEST (NO COMMAS)"
LOCATE21 5 INPUT" MSGS
END IF
LOCATE 22 5 PRINT-ONTINUE OR ETURN TO SETUP -. CONS
LOCATE 22. 37 INPUT CONS
WEND
FILEDWNS = DRVS * -T * DFNS * ' OWN" DOWNHOLE DATA FILE
• OPEN FILEDWNS FOR APPEND AS *1
FILETOPS = DRVS * T » DFNS » • TOP" TOPSIDE DATA FILE
• OPEN FILETOPS FOR APPEND AS «2
END SUB
N10
-------
APPENDIX N, ATTACHMENT 3, PROGRAM: PERMTST1.DOC
DECLARE SUB SAVDSK (SS P% FILETOPJ MSGS)
COLOR? 1
•' ii > PERMTEST BAS W HOUOWAY 9/5/94
PERMEABILITY TEST PROGRAM
CLS
PRINT - OSU ERDL DATA ACQUISmON PROGRAM-
PRINT' DEVELOPED FOR EPA OOWNHOLE PROJECT-
VIEW PRINT 3 TO 25 CLS
LOCATE 7. 31 PRINT-PERMEABILITY TEST-
LOCATED 33 PRINT "SETUP ROUTINE'
CALL SAVDSKfSK. P* FILETOPJ MSGS) 'SETUP DATA FILES IF SAVE
CLS
DEL* = 0 "SET DELAY FLAG FOR TIME R/CH=99
IF SS = 1 THEN
ON TIMER(PK) GOSUB DELAY DELAY TIMER INTERVAL TO SAVE DATA
TIMER ON
END IF
DO
WHILE INKEYS o CHRS(27) IOOP WHILE ^SC KEY NOT PRESSED
'' > INFTIAUZE DRIVER USING FUNCTION 0
•CLS
DMDAT%(4) ARY1»(100). ARY2V100) 'CREATE ARRAYS
PORT* = &HZZO 'SET I/O PORT BASE ADDRESS
DATK(O) = PORT* -GET VO PORT BASE ADDRESS
ERW = 0 'INFTIAL ERROR VALUE
FUN%°0 •INrTIAL FUNCTION VALUE
CALLPCL711(FUN%. SEGDATK(O) SEG ARY1%(0). SEG ARY2*(0) ER%)
IF ER% « 0 THEN PRINT DRIVER INITIALIZATION FAILED1 (FUNCHO)' STOP
' SET PCL-711 INPUT CHANNEL
FUN* = 1
READ CH -READ SIG COND CHANNEL NUMBER FROM DATA
IF CH = 29 THEN R* = 3 ELSE RK » 0
DATK(O) = R*
CALL PCL71KFUNK SEG DATW(O). SEG ARY1%(0). SEG ARY2%(0). ERK)
IF ER% <> 0 THEN PRINT "SET SCAN CHANNEL FAILED1 STOP-
LOCATE 24.1 0
'= > OBTAIN DATE AND TIME FOR THIS SAMPLE
LOCATE 3 60 PRINT "DATE '. DATES
LOCATE 4. 60 PRINT TIME -. TIMES
•====="-—> SELECT CHANNEL ON SIG COND TO MONfTOR USING FUNC 21
FUN% = 21
•READ CH • READ SIG COND CHANNEL FROM DATA
DATW(O) = CH
IF CH = 99 AND DEL* = 1 AND S% = 1 THEN
GOSUB GETTME
RESTORE
DELS = 0
ELSEIF CH = 99 THEN
RESTORE
END IF
CALL PCL711 (FUNK SEG DAT%(0) SEGARY1%(0) SEGARY2U(0) ERS)
IF ERV <> 0 THEN PRINT "SELECT CHANNEL TO MONITOR FAILED (FUN21)' STOP
•== '=> PERFORM A/D CONVERSION USING FUNC 3
FUNS = 3
DATK(O) = 0 'ANALOG CHANNEL ON PCL-711
FOR O = 1 TO 6000 NEXT O "DELAY LOOP TO ALLOW A/D TO SETTLE
N11
-------
CALL PCL711(FUN* SEG DAT*(0) SEGARY1%(0) SEGARY2%(0) ERH)
IF ERS <> 0 THEN PRINT 'A/D CONVERSION FAILED'" STOP
IF S% = 1 THEN LOCATE 4 1 PRINT "SAVE OUT ELSE PRINT "SAVE OFF"
LOCATE6 1 PRINT USING "V* -. Rtt CH
•==«=» CONVERT ANALOG SENSOR INPUT DATA INTO USABLE FORM
DATK(O) = DATK(O) * 2048
LOCATE 8 1 PRINT USING " MMW DAT%(0)
IF CH = 3 THEN CH3 = -810 29 » 1 00392 • DAT%<0) - 000017 • DATS(O) • 2 IF CH3 < 0 THEN CH3 = (TICS 3000PSI/FLMTR STAND
IF CH = 3 THEN DPS •= DAT%(0)
IF CH = 4 THEN CH4 = -262 S94 » 322cm * DATK(O) - 000003 • DATtt(O) • 2 IF CH4 < 0 THEN CH4 • (TICS 1000PSVOD RES
IF CH = 4 THEN OP4 = DATK(O)
IF CH = 15 THEN CH1S = (DATK(O) / 12 3664)» 5 STB
IF CH = 16 THEN CH16 = (DATK(O) / 12 3664)« 3 4T9
IF CH = 17 THEN CH17 = (DAT%(0) /12 3664) * 2 7T10
IF CH = 29 THEN CH29 - -51 6783 • 02478E • OATH<0) 'IF CH29 < 0 THEN CK29 = OVAL 50PSI
IF CH = 29 THEN DP29 = OAT%(0)
IF CH = 32 THEN CH32 = DAT%(0) • (5 / 2048) TEMPO 1
IF CH = 40 THEN CH40 = DATK(O) • (5/2048) TEMPO 2
IF CH = 48 THEN CH48 = OAT«<0) • (5 / 2048) TEMPO 3
' DISPLAY TOP SIDE SENSOR DATA
LOCATES 45 PRINT TOP LOC SENSOR READING-
LOCATE 9. 54 PRINT USING ' SWINJ MM • PSf; CH3 'IP-8
LOCATE 10. 54 PRIMT USING 'OD RES MM*PSrCH4'
LOCATE 11. 54 PRINT USING " 50 PSI MM * PSf. CH29
LOCATE 14 54 PRINT USING " VERTEMP •*» * «F* CH15 T-6
LOCATE 15. 54 PRINT USING • BPCTEMP ••» « eF": CH16 T-9
LOCATE 16. 54 PRINT USING ' SISTEMP M**aF-. CH17T-10
LOCATE 21. 54 PRINT USING ' BPC M «W VOLTS* CH32 TMPO-1
LOCATE 22. 54 PRINT USING • SIS M MM VOLTS'. CH40 TMPO-2
LOCATE 23. 54 PRINT USING-VER M M* VOLTSI CH48 TMPO-3
WEND
•' CLOSE AND EXIT
CLS
LOCATE 10. 5 INPUT ' ONTINUE OR EIT> - ES
SELECT CASE ES
CASE 1C". V
CLS
CASE -X-. -X-
IF SV = 1 THEN
LOCATE 15.10 PRINT "PLEASE WWT WHILE DATA FILES ARE BEING CLOSED-
OPEN FILETOPS FOR APPEND AS *2
PRINTK ^WINJ.-: -ODRES-. "SOPSI*
PRINT*2. •VERTMP."1BPCTMP-.-SISTMP.-:-BPC .I'SIS "VER -
PRINT n. DATES
PRINT n.".
PRINT *2. MSGS
CLOSE
FOR X = 1 TO 10000- NEXT X
END IF
CLS END
END SELECT
CLS
LOOP
-> SAVE ANALOG DATA TO DISK
DELAY
DEL% = 1 "SET DELAY FLAG TO ON
RETURN
N12
-------
GETTIME -SUBROUTINE TO SAVE DATA TO DISK
OPEN FILETOPS FOR APPEND AS »2
PRINT *2 USING TWO* - OP3 OP4 OP29
PRINT « USING TRWWS- CH15
PRINT 92. USING •**» «• CH16 CH17
PRINT «2 USING f» •*» - CH32 CH40. CH48
PRINT « " TIMES
CLOSED
RETURN
•DATA POLLS MULTIPLEXED SENSOR INPUTS
DATA 3 4 15.16 17.29.32 40 48 99
SUBSAVDSK(S% PH FILETOPS MSGS)-SK*SAVE FLAG P*=TIME INTERVAL FOR SAVE
WHILE CONS <> -C-
LOCATE 105 INPUT -SAVE DATA TO DISK (Y/N) -. SAVS
WHILE SAVS <> tT AND SAVS «> Tr AND SAVS of AND SAVS <> V
LOCATE 10.29 INPUT SAVS
WEND
IF SAVS »TT OR SAVS '"nm THEN SX = 0 EXIT SUB
IF SAVS = -VOR SAVS = VTHEN SW = 1 ELSE S% « 0
LOCATE 12.5 INPUT -WHICH DRIVE (A.B C D ) " ORVS
WHILE DRVS o "A- AND ORVS <> "B" AND DRVS <> "C" AND DRVS <> TT
LOCATE 12.28 INPUT ORVS
WEND
LOCATE 14. 5 INPUT "WHAT DATA FILE NAME (DO NOT TYPE EXTENSION) -. DFNS
WHILE DFNS = -
LOCATE 14.49 INPUT DFNS
WEND
LOCATE 16. 5 PRINT "PERIOD OF TME BETWEEN SAVING DATA (IN SECONDS)": P%
LOCATE 16 53 INPUT PH
LOCATE 18 5 PRINT "DATA WILL BE SAVED TO DRIVE • '. DRVS. " ' AS FILE ' DFNS. ' PRKT
LOCATE 19. 5 PRINT "AT AN INTERVAL OF • P% • SECONDS-
IP S% = 1 THEN
LOCATE 20. 5 PRINT -ENTER COMMENTS FOR THIS TEST (NO COMMAS)'
LOCATE 21.5 INPUT - -. MSGS
END IF
LOCATE 22. 5 PRINT -ETURN TO SETUP -. CONS
LOCATE 22. 37 INPUT CONS
WEND
FILETOPS •= DRVS » *»' • DFNS » - PRUT -PERMEABILrTV DATA FILE
END SUB
N13
-------
APPENDIX N, ATTACHMENT 4, PROGRAM: MUDTEST.BAS
SO COLOR 7 1
100CLS
200 PRINT' OSUERDL DATA ACQUISITION PROGRAM-
300 PRINT - DEVELOPED FOR MPT MUD TEST EPA PROJECT
400 PRINT
SOO PRINT
1410 •====> MUDTESTBAS 2O3/94. WHOLLOWAY
1415- »MtP PROGRAM
1420 > SETUP TO SAVE INPUT DATA TO DISK
1425'
1430 VIEW PRINT 3 TO 25
1435 CLS
1440 LOCATE 6 5 PRINT 1/0 PORT BASE ADDRESS (SW) IS SET TO HEX 2W
1450 LOCATE 4. 30 PRINT • SETUP ROUTINE'
1500 LOCATE 10 5 INPUT "SAVE DATA TO DISK* (V/N) 1 SAVS
1510 IF SAVS = TT OR SAVS <= V THEN GOT01800 ELSE GOT01600
1600 LOCATE 12 5 INPUT-WHICH DRIVE (A.BC V»":DRVS
«2! ,L2^I! 'f ? ltlPUT "WHAT DATA FILE NAME WOULD YOU LIKE T0 USE' 'D0 NOT ™*E EXTENSION)». DFNS
1620 LOCATE 16. 5 PRINT DATA WILL BE SAVED TO DRIVE • '. DRVS. • • AS FILE • DFNS
1630 IF SAVS c -r OR SAVS = V THEN S* = 1 ELSE S% = 0
1700 DTS 2 DATES
1710 TIMES • -TOOo-oo- TIMER ON
1800 SOU = 0 SOO*=0
1805 LOCATE 17.5 INPUT - TART PROGRAM OR EIGH SAMPLE • CS
1810 IF CS = -S-1 OR CS = V GOTO 1350 ELSE IFCS = -WORCS = V GOTO 9000
1890' > INrTIAUZE DRIVER USING FUNCTION 0
1900'
1950 CLS
2000 DM DAT%(4) ARY1V600) ARY2*(6OO) -CREATE ARRAYS
2100 PORT* = &K220 -SET I/O PORT BASE ADDRESS
2200 DAT*(0)« PORT* 'GET VO PORT BASE ADDRESS
2300ER* = 0 -INITIAL ERROR VALUE
2400 FUN* = 0 -INrTIAL FUNCTION VALUE
2500 CALL PCL71KFUN* SEG DAT%(0). SEG ARY1%(0) SEGARY2%{0) ER%)
2600 IF ER% «> 0 THEN PRINT DRIVER INITIALIZATION FAILED' (FUNCKOP STOP
2700 DTS = DATES
2710 TIMES = -OO-OaOO- TIMER ON
2800 > SCAN CHANNEL USING FUNCTION 1 AND OPEN DATA FILE
2810'
2900 DATW(O) = 0
3000DAT*(1) = 5
3100 FUN% = 1
3200 CALL PCL711(FUN% SEG DAT%(0) SEGARY1%(0) SEG ARY2%(0). ER%)
3300 IF ERS <> 0 THEN PRINT "SET SCAN CHANNEL FAILED' STOP-
3400 FILEDIGS = DRVS . T * DFNS * - DIG' IF 5% = 1 THEN OPEN FILEDIGS FOR APPEND AS ft
3410 FILEANAS = DRVS • T * DFNS * ".ANA" IF SK = 1 THEN OPEN FILEANAS FOR APPENDAS M
3430 OPEN-COM2 2400 N 8 1.LF-FOR RANDOM AS »4-OHAUS SCALE ^--—-^
3510 LOCATE 24 1 0
3590
3600 •====» STEP 3 READ DIGITAL DATA USING FUNCTION 22
3605'
3610 FOR Y = 1 TO 50 'SAMPLE DIGITAL DATA 10 TIMES FASTER THAN ANALOG DATA
3620 FOR X = 1 TO 10 NEXT X 'DELAY LOOP
3640 IF INKEYS •= CHRS(27) GOTO 7310
3700 'OBTAIN DATE AND TIME FOR THIS SAMPLE
3710 LOCATE 4 60 PRINT "DATE ' DTS
3720 LOCATE 5 60 PRINT TIMER ' TIMER
4000 FUN* = 22
4100 CALL PCL711(FUN* SEG DAT*(0) SEG ARY1*(0). SEG ARY2*(0) ER*)
4200 IF ER* <> 0 THEN PRINT -READ DIGITAL DATA FAILED' (FUN*22)- STOP
4300 IF DATK(1) < 128 THEN Dl* = DATK(O) * DAT*(1) • 256
4400 IF DAT*(1) > 127 THEN 01* = (DAT*(1) - 256) • 256 » DAT*{0)
4405 'LOCATE 17. 9 PRINT USING "D/l DEC MMT Dl*.
4406 LOCATE 19 4 PRINT "HEX - HEXS(DIS)
44081
N14
-------
4420 FOR I = 1 TO 4
4430 PS = HEXSTDIH)
4440 FIXS • MIDSfPS I 1)
4450 IF FIXS = "F-THEN Dl = TJOOO'
4460 IF FIXS = -E-THEN OS = '1.0 00 "
4470 IF FIXS = TJ- THEN OS = "0 1 0 0 "
4480 IF FIXS = "C-THEN DS = "1 1 0.0 -
4490 IF FIXS = -B" THEN DS = "0 0 1 0 •
4500 IF FIXS = -A- THEN DS = 1.0 1 0 "
4510 IF FIXS = -9"THENDS = "O.1 1 0"
4520 IF FIX* = V THEN D$ =-11.10"
4530 IF FIXS = T THEN OS = TO 0 0 1 "
4540 IF FIXS = -6" THEN OS = "I 0.0 1 "
4550 IF FIXS = "5-THEN OS = TD 1 0 1 •
4560 IF FIXS •= "4- THEN DS = "1 1 0 1 •
4570 IF FIXS = T THEN DS = TQ.O 1 1 "
4580 IF FIXS = f THEN DS = "1 01 1 "
4590 IF FIXS = -1-THEN DS = ~0 1 1 1 -
4600 IF FIXS = TT THEN OS = no 0.0.0."
4610 IF I = 1 THEN GOTO 4660
4620 IF I a 4 THEN LOCATE 22 10 PRINT OS
4630 IF I • 3 THEN LOCATE 22. 20 PRINT DS.
4640 IF i = 2 THEN LOCATE 22 so PRINT os.
4660 NEXT I PRINT-
4800'
4810 IF Y = 7 THEN LOCATE 9 40 PRINT • • 'CLS FOR ALARM
4820 IF V = 7 THEN LOCATE 8. 40 PRINT " -. 'CLS FOR ALARM
5010 IF HEXS SCALE«1 SETUP INSTRUCTIONS (LARGE SCALE)
5310'
5420 • SCALE SETUP WITH SCALE OFF. PRESS "RE-ZERO' WITH TIN" TO BRING UP
5430' PARAMETER SETTINGS PRESS -PRINT" TO CHANGE TO "GROUP B SETTINGS-
5440 • PRESS "RE-ZERO" TO MOVE CURSOR UNDER NUMBER TO CHANGE
54SO-GROUP B SETTING SHOULD BE M3Q22 3 - COMMAND MODE. 0 • 2400 BAUD
5455' 2 - NO PARITY. 2 - 8 BIT/1 STOP BFT
5460-
5500 OHAUS SCALE SUBROUTINE
5510 PRINT *4 t>D" • -P" • CHRS(13) * CHRS(IO) ———
5515 IF NOT EOF(4) THEN OHSCS = INPUTS(LOC(4). «4) FOR X = 1 TO 5 NEXT X
5516 OHSC = VA1JOHSCS)
5520 • SCALE SETUP RS232 PARAMETERS (iS232)- 2400 BAUD, NO PARITY 8 EFTS.
SS30M sroPBrr THIS is SETUP AS frs: ~ow is FOR TURN OFF 1 SEC DELAY
5540 • -P- IS FOR PRINT DATA. CHRS(13) IS CARRIAGE RETURN. CHRS(10) IS LINE FEED
5550'
5900 ii i > PERFORM Art) CONVERSION USING FUNC 3
5905*
5910FORC = 1TO6 'NUMBER OF ANALOG CHANNELS TO SAMPLE
6000 DATH(O) = 0
6100 FUNK = 3
6150 FOR O = 1 TO 10& NEXT 0 DELAY LOOP TO ALLOW Art) TO SETTLE
6200 CALL PCL711(FUN% SEGDAT%(0) SEGARY1%(0) SEG ARY2%(0). ERH)
6300 IF EPS o 0 THEN PRINT "A/D CONVERSION FAILED1"- STOP
6390'
6400 •====> CONVERT ANALOG SENSOR INPUT DATA INTO USABLE FORM
6405
6410 P1 = (1231 - DAT%(0)) * (500 / 2970) IF P1< 0 THEN PI = 0
642OP2-=(1221 -DATS(0))-(50/2970) IF P2
-------
6470 •====«=» PRINT TO SCREEN
6475 •SO* = 0 SOOK = 0
6480 IF INKEYS = CHRSI32) THEN SO* = 1 TURN OFF P40 ALARM WITH HFT ANY KEY
6485 IF SDK = 1 AND INKEYS = CHRS(32) THEN SOO% = : TURN OFF P400 ALARM WITH HPT ANY KEY
6486'LOCATE 4 3 PRINT -S0%=- SO*
6487'LOCATE 5 3 PRINT "SOOW=- SO*
6490
6500 -PRINT USING- CH-M READING WNMW - DAT*(1) DAT*{0)
6510-LOCATE 7 3 PRINT USING XHTW READING «***- DAT%(1) DAT*(0)
6520 IF DAT%(1) = 0 THEN LOCATE 8 3 PRINT USING ' P500 = «*» * PS I" PI • PRINT OATS(O) 'CH 0 500 PSI
6530 IF DATW(1) = 1 THEN LOCATE 9 3 PRINT USING • P50 = M * PSP P2 ' PRINT DAT%(0) 'CH 1. 50 PSI
6540 IF DAT%(1)s 2 THEN LOCATE 10 3 PRINT USING • THERM = MWOeF- TH1. 'PRINT DAT%(0)
6550 IF DAT*(1) = 3 THEN LOCATE 13 3 PRINT USING 'TEMP3= M**aF-T3 • PRINT dalS(O) 'CH 5
6560 IF DATM(I);: 4 THEN LOCATE 12 3 PRINT USING-TEMP2 = •*»*eF-T2 ' PRINT OatU(O) 'CH 4
6570 IF DATK(1)c 5 THEN LOCATE 11 3 PRINT USING " TEMPI = OWC0F-T1 • PRINT datK(O) 'CH 3
6572 LOCATE 14 3 PRINT USING-COM2 O-SCALE = *o» « g". OHSC
6573 IF DATUM) = 0 AND P1 >= 400 AND SOOS « 0 THEN LOCATE 9 40 PRINT XAUTION - PI OVER 400 PSI '"• SOUND 3500 1
6575 IF DATK(1) = 1 AND P2 >= 40 AND SOS = 0 THEN LOCATE 8 «t PRINT T>2 OVER 40 PSI - CLOSE VALVE'"- SOUND 3000 1
6590' ii i> SAVE ANALOG DATA TO DISK
6600'
6610'IF S*=1 THEN PRINTK PI. •» P2 " L1 " T1 "T2 " T3
6620 IF S* « 1 AND DAT*(1) = 0 THEN PRINT n. USING tmt«.-. P1 '500 PSI
6630 IF S% - 1 AND DATK(1) = 1 THEN PRINT K. USING TW ff 1 P2 '50 PSI
6640 IF S% •= 1 AND DAT*(1) = 2 THEN PRINT *2. USING 1M» 0 '. TH1.
6650 IF SS = 1 AND DAT%(1) = 3 THEN PRINT «2 USING •**»«". T1
6660 IF S* = 1 AND QAT*(1) = 4 THEN PRINT 92 USING •** *.- T2
6670 IF S% = 1 AND DATK(1) = 5 THEN PRINT t2 USING f*» *.'. T3
6672 IF SS » 1 AND C = 6 THEN PRINT *2 USING •*•» * •; OHSC 'OHAUS SCALE
6685 IF S% e 1 AND C = 6 THEN PRINT K HEXS CLOSE AND EXfT
6820'
6900 LOCATE 25 3 PRINT • PRESS TO EXIT •
7100 AS = INKEYS IF M- CHRS(27) THEN GOTO 7105 ELSE GOTO 7210
7105 CLS • LOCATE IS 3 PRINT "PLEASE WATT WHILE DATA FILE IS BEING CLOSED'
7200 IF C a 6 THEN GOTO 7310
7210 NEXT C
7300 GOTO 3600
7310 IF S% = 1 THEN PRINT « -P500.--PXr-THRM-.- T1.V T2." T3.~ • O-SC " HEX. - - TIME - DTS
7311 IF S% = 1 THEN PRINT t1. '. '. DTJ
73121
7315 • =>WEIGH SAMPLES USING LARGE SCALE
7320'
9000 CLS CLOSE
9115 IF S% = 0 THEN GOTO 9230
9120'
9210 '»= i i OPEN DATA FILE AND SETUP SCALE
9220 FILESCAS = DRVS » T » DFNS » • SCA' IF S% = 1 THEN OPEN FILESCAS FOR APPEND AS «5
9230 CLS LOCATE 10 5 INPUT-EZERO SCALE. IT -. RVW
9240 IF RVW = ft- OR RVW = V THEN RWK = 1 ELSE RWK = 0
9250 IF RVW = -W OR RVW = "V THEN RWK = 2 ELSE RWK = 0
9255 IF RVW = TT OR RVW = V THEN GOTO 9800
9260 IF RWK = 1 THEN GOTO 9300
9270 IF RWK = 2 THEN GOTO 9500
9290 REZERO SCALE
9300 OPEN -COM12400.N 8.1 LF~ FOR RANDOM AS «3 FORD = 1 TO 1000 NEXTD
9310 PRINT *3 "FT FOR R = 1 TO 10000 NEXT R CLOSE f3
9320 LOCATE 14 5 PRINT "SCALE HAS BEEN RE-ZEROED"
9500 '= i .LI WEIGH SAMPLE
9510 LOCATE 16. 5 INPUT TROCEDE TO WEIGH? (Y/N). WILL TAKE YOU BACK TO REZERO SCALE' PS
9520 IF Pi = -W OR PS = TTTHEN GOTO 9230
9530 OPEN -COM1.24OO N.B 1.LF- FOR RANDOM AS *3 FOR D = 1 TO 1000 NEXT D
9540 PRINT f 3 -Q- FOR R = 1 TO 10000 NEXT R
9550 IF NOT EOF(3) THEN SCS = INPUTS(LOC(3) «3) FOR E = 1 TO 1000- NEXT E
9560SCS = MIDSISCS 4 9) SC = VAL(SC$) CLOSER
9570 •=— —>PRINT DATA RESULTS TO SCREEN & DATA FILE
9600 LOCATE 18. 5 PRINT USING 1MM « B-. SC IF SK = 1 THEN PRINT *5. USING HNMW « g. ' SC
9610 LOCATE 20 5 IF S% = 1 THEN PRINT "ENTER COMMENTS FOR THIS SAMPLE - KEEP (T SHORT' - OR * MSGS
9615 LOCATE 20 5 IF S* = 0 THEN PRINT "DATA NOT BEING SAVED FOR THIS SAMPLE - '
9620 LOCATE 21 5 INPUT-"MSGS IF SS = 1 THEN PRINT *5 MSGS
9630 '==- =>DO IT AGAIN
9700 CLS LOCATE 10 5 INPUT 'WEIGH ANOTHER SAMPLE' (Y/N)' SAS
9710 IF SAS = "Y- OR SAS = V THEN GOTO 9230 ELSE GOTO 9800
9800 -==»===>CLOSE AND EXIT
9810 IF SK = 1 THEN PRINT «5 OTS CLOSE TIMER OFF CLS
9820 LOCATE 15 3 PRINT "DATA & COM FILES CLOSED" END
N16
-------
APPENDIX N, ATTACHMENTS, PROGRAM: DELTA3T.BAS
DECLARE SUB SENS1ORSOR9 (PS. VI I'. DS S% TS)
DECLARE SUB VALVE (PS. VS)
DECLARE SUB SAVDSK (S% OUTFILES)
DECLARE SUB SENS2OR6 (PS VS I1. DS SS TS)
DECLARE SUB SENS3OR7 (PS. VS. I1. DS. SS TS)
DECLARE SUB SENS4OR8 (PS VS I'. DS SV TS)
DECLARE SUB SENS1ORSOR9 (PS. VS l>. DS SV TS)
= DELTA1 BAT 6/17/94 W HOLLOWAY
COLOR 7.1
CLS
PRINT* OSU ERDL CONVERT PROGRAM-
PRINT- DEVELOPED FOR MPT MUD TEST EPA PROJECT-
PRINT - FOR DETERMINING DELTA TIME FROM RAW DATA'
PRINT
VIEW PRINT 3 TO 25
CLS
LOCATE 11.15 PRINT "WHICH DATA FILE TO READ (•EXTENSION)-.
LOCATE 12. 15 INPUT TTVPE DRIVE FILENAME IE -. MFILES
LOCATE 24 1.0
CALL SAVDSK(S%. OUTFILES)
CLS
LOCATE 23. 10 PRINT "DATA IS NOT BEING SAVED" PRINT
END IF
LOCATE 12. 15 INPUT "SELECT NE SENSOR OR LL SENSORS-. ALLS
IF ALLS = -0- THEN
LOCATE 14. 15 INPUT "WHICH SENSOR (1-9) - WHCS
FD% = VAL(WHCS) - 1
L% = 1
ELSEIF ALLS' -A* THEN
L% = 9
END IF
OPEN INFILES FOR INPUT AS »1
FD% = FDS * 1
FDS - RIGHTS(STRS(FDU) 1)
NEWFILES = OUTFILES » FDS
IF FDS = "CT THEN PRINT THE END' END
LOCATE 21. 10 PRINT NEWFILES
IF S* = 1 THEN OPEN NEWFILES FOR APPEND AS W2
• STRIP OUT DESIRED SENSOR FROM HEX VALUE
CLS
SELECT CASE FDH TLOW DETECTOR NUMBER
CASE1
I'= 2
SENS* £ 1
CALL SENS1OR5OR9(PS VS I1. DS SW TS)
CASE 2
l> = 3
SENS* •= 2
CALLSENS20R6(PS VS I'.DS.SVTS)
CASES
N17
-------
I1 = 3
SENS* = 3
CALL SENS3OR7(PS VJ l> OS S* TS)
CASE 4
SENS* = 4
CALL SENS4OR8(PS VS P. DS SK TS)
CASES
SENSK = 5
CALL SENS1OR5OR9(PS VS I' DS SK TS)
CASES
I'= 4
SENSK = 6
CALL SENS2OR6(PS VS I'. OS SK TS)
CASE?
I' = 4
SENSK>7
CALL SENS30R7(PS. VS I'. DS. SK. TS)
CASE 8
SENSK = 8
CALL SENS4ORB(PS VS I'. DS. SK TS)
CASE 9
SENSK = 9
CALLSENS10R50R9(PS.VS l< DS. SK TS)
END SELECT
IF EOF(1) = -1 THEN
PRINT T< M L" STRT - • STOP ~ ' TMEF - • PLOT •• • TMEBD - • BDRT •
END IF
IF EOF(1) = -1 AND SK = 1 THEN
PRINT «2. -R.ML.V STRT. • • STOP I ' TIMEF-.- FLOT. -. • TMEBD V BDRT -
CLOSE *2
END IF
CLOSE
NEXTX
SUB SAVDSK (SK. OUTFILES)
WHILE CONS » T-
LOCATE 14. IS INPUT "SAVE DATA TO DISK (YM) - SAVS
WHILE SAVSo TT AND SAVS o TT AND SAVS o "V AND SAVS o V
LOCATE 14. 39 INPUT SAVS
WEND
IF SAVS = -V OR SAVS = V THEN SK = 1 ELSE SK = 0
LOCATE 16 15 INPUT "WHICH DRIVE (A.B C ) -. DRVS
WHILE DRVS o 'A' AND DRVS <> "B" AND DRVS o V
LOCATE 16. 38 INPUT DRVS
WEND
LOCATE 1815 INPUT "WHAT DATA FILE NAME (DO NOT TYPE EXTENSION) -. DFNS
WHILE DFNS = ~
LOCATE 18 59 INPUT DFNS
WEND
OUTFILES = DRVS *•!•• DFNS*-CO"' DATA FILE-
LOCATE 21.5 PRINT -DATA WILL BE SAVED TO - OUTFILES
LOCATE 23 5 PRINT-ONTINUE OR ETURN TO SETUP -.CONS
LOCATE 23 40 INPUT CONS
IF CONS o -C- THEN CLS
WEND
END SUB
SUB SENS1ORSOR9 (PS. VS. I1. DS SK TS)
STP' = 0
TIMEF i = 0
TIMEBD' = 0
STRTI' = 0
COUNT' = 1
DO UNTIL EOF(1)
DO WHILE EOF(1)<>-1
INPUT »1 PJ T' "INPUT FIRST DATA
FIX1S»MIDS(PS l< 1)
N18
-------
oi$ * tr
IFFIX1S = -E-THEND1S = -1" 'BLANK OUT V DATA
IF FIXIS = -C-THEN DIS = -1-
IF FIX1S = -A- THEN D1S = T
IF FIXIS = "8" THEN D1S = -T
IF FIX1S = -6- THEN D1S = "T
IF FIXIS = -4- THEN D1S = •!•
IF FIX1S = T THEN D1S = 1"
IF FIX1S = TT THEN D1S = T
•PRINT T'
IFD1S = TTHEN
CALL VALVE(PS VS)
STRT' = T'
STRT2' « STRT'
EXIT DO
END IF
IFEOF(1) = -1THEN
EXfTDO
END IF
LOOP
STP2' = STP1
DOMMILEEOF(1)<>-1
STPPi = T' "PRIOR TIME
INPUT *1.PJ T'
FIX2S = MIDS(PS I' 1)
D2S = V
IFFIX2S = TTHEND2S = 1- -BLANK OUT V DATA
IF FIX2S = -C-THEN D2S = I"
IF FIX2S = -A-THEN D2S = T
IF FIX2S = TTHEN D2S = 1-
IF FIX2S = T-THEN O2S • 1'
IF FIX2S = T THEN D2S = 1'
IF FIX2S = T THEN D2S = 1-
IF FIX2S = TT THEN D2S = T
STP' = STPP"
Exrroo
END IF
IFEOF(1> = -1THEN
EXIT DO
END IF
LOOP
IFEOF(1) = -1 THEN
EXIT DO
END IF
FLOW = STP'. STRT'
IF STRT' > STP1 THEN
FLOW ° 86400 - STRT' * STP'
END IF
BDRT' = STRT2' - STP2'
IF BDRT' = STRT'THEN
BDRT' = 0
END IF
IF STP2" > STRT2' THEN
BDRT' = 86400 - STP2' * STRT2'
END IF
TIMEF' = TIMEF' » (STRT2' - STRTI')
TIMEBD' = TIMEBD'«(STpi - STP2')
IF COUNT' : 1 THEN
TIMEBD' = FLOW * TMEF'
END IF
COUNT' = 2
STRTI' = STRT'
PRINT Vt • '.
PRINT USING I**** •» - STRT' STP' TIMEF' FLOW TIMEBD'. BDRT'
PRINT n VS ' '
PRINT *2. USING •*••»• Mr - STRT' STP' TMEF' FLOW. TIMEBD'. BDRT'
LOOP
END SUB
N19
-------
SUB SENS2OR6 (PS Vt I' OS SV TS)
STP' = 0
TIMEFi - 0
TIMEBD' = 0
STRTI' = 0
COUNTi = 1
DO UNTIL EOF<1)
DO WHILE EOF(1) <>-1
INPUT/H PS T' 'INPUT FIRST DATA
FIX1S = MIDS(PS I' 1)
D1S = -tr
IFFIX1S = V-THEND1S = T 'BLANK OUT 'ff DATA
IF FIX1S = T THEN D1S = -I"
IF FIX1S = -5- THEN D1S = 1"
IF FIX1S = -4- THEN D1S = T
IF FIX1S = T THEN O1 S = T
IF FIX1S = T THEN D1S = T
IF FIX1S • 1-THEN D1S = T
IF FIX1S = TT THEN D1S = I"
•PRINT T'
IFD1S = 1-THEN
CALL VALVE(PS VS)
STRT'sT1
STRT21 » STRT1
Exrroo
END IF
IFEOF(1)=-1 THEN
Exrroo
END IF
LOOP
DO WHILE EOF(1) o-1
STPPi = Ti "PRIOR TIME
INPUT »1. PS P
FOQS = MIDS(PS. I'. 1)
-7-THEND2S = -1" -BLANK OUT V DATA
IF FIX2S = •6* THEN D2S - -I"
IF FKM = "5" THEN D2S = T
IF FDQS = -4- THEN D2S = 1"
IF FDOS = TTHEN D2S = T
IF FR2S = "7- THEN D2S = T
IF FDOS = -1 • THEN D2S = f
IF FUOS = TT THEN D2S = I •
STP' = STPP'
EXIT DO
END IF
IFEOF(1)--1THEN
EXFTDO
END IF
LOOP
IFEOF(1) = -1THEN
EXIT DO
END IF
N20
-------
FLOW s STP<. STOP
IF STKTi > STf> THEN
FLOW = 86400 - STRT> - STP'
END IF
BDRT' = STRT2' - STP2'
IF BDRT' = STRTi THEN
BDRT' = 0
END IF
IF STP2J > STRT2' THEN
BDRT' = 86400 - STP2> » STRT2'
END IF
TIMEF' = TIMEF> • (STRT2' - STRTI')
T1MEBD' = TIMEBD' * (STP' - STP2')
IF COUNT' = 1 THEN
TIMEBD' = FLOW * TIMEF'
END IF
COUNT' = 2
STRTI' = STRT'
PRINT VS ' -.
PRINT USING •»«••»•» - STRTi. STP> TIMEF'. FLOW TIMEBD'. BDRT'
PRINT K VS m ••
PRINT n. USING WHNMM - STRT'. STP'. TIMEF'. FLOW. TIMEBD'. BDRT'
LOOP
END SUB
SUB SENS3OR7 (PS. VS I'. Dt S% TS)
STP' = 0
TIMEF' = 0
TtMEBD" = 0
STRTI' = 0
COUNT' = 1
DO UNTIL EOF(1)
DO WHILE EOF(1) o-1
INPUT «1. PS. T< 'INPUT FIRST DATA
FIX1$ = MIDS(PS l'.1>
D1S = TT
IFFIX1S = 'B"THEND1S = 1" BLANK OUT tr DATA
IF FK1S = -A-THEN D1S = T
IF FK1S = -9- THEN D1S = T
IF FK1S = -B- THEN D1S = T
IF FK1S = T THEN D1S = f
IF FK1S = T THEN Dlf » T
IF FK1S = 1- THEN D1S = T
IF FIX1S = TT THEN D1S = T
•PRINT T'
IFOIS'1-THEN
CALLVALVE(PJ.VJ)
STRT' o T'
STRT2' = STRT'
EXfTDO
END IF
IFEOF(1) = -1THEN
EXIT DO
END IF
LOOP
DO WHILE EOF(1) <>-1
STPPi = T' 'PRIOR TME
INPLTT«1 PS T'
FIX2S = MIDS(PS. I' 1)
D2$ = TT
IF FIX2S = -B- THEN D2S = T "BLANK OUT V DATA
IF FIX2S = "A" THEN D2S = T
IF FIX2S = T THEN D2S • T
IF FIX2S = T THEN D2S = T
IF FIX2S = T THEN D2S = T
IF FIX2S = -F THEN D2S = T
IF FIX2S = 1-THEN D2S = T
IF FOQS = TT THEN D2S = T
IF 02$ = VIXEN
STP' = STPP1
Exrroo
END IF
N21
-------
IFEOF(1) = -1THEN
EXIT 00
END IF
LOOP
IFEOF(1) = -1 THEN
EXIT DO
END IF
FLOW = STP' - STRT'
IF STRT' > STPi THEN
FLOW = B64OO - STRT' . STP'
END IF
BDRTi = STRT2' - STP2"
IF BDRTi = STRT' THEN
BDRTi = 0
END IF
IF STP2' > STRT2' THEN
BDRTi = 86400- STP2' * STRTZ'
END IF
TIMEF- = miEFi * (STRT2I - STRTI')
TIMEBD' = TWEED' • (STP' - STP2')
IF COUNT- =1 THEN
TIMEBD' e FLOW • TMEF'
END IF
COUNT' = 2
SIKH' = STRT'
PRINT VS ' '.
PRINT USING -VMM *». -. STRT". STP'. TWEF' FLOW TMEBD'. BDRTI
PRINT *2. VS." •
PRINT K USING TWWt* •*. -. STRT'. STPi. TMEF'. FLOW. TMEBD'. BORT'
LOOP
END SUB
SUBSENS40RB(PS VS I'.DS.SK.TS)
STP'sO
TIMEBD' = 0
STRTI' = 0
COUNT' s 1
DO UNTIL EOF(1)
DO WHILE EOF(1) o-l
INPUT *1 PS. T' 'INPUT FIRST DATA
FIX1S e MIDS(PS. I'. 1)
D1$ = TT
IFFIX1J = -D-THEND1» = 1- -BLANK OUT T DATA
IF FK1S = "XT THEN D1S = T
IF FIXU = "9- THEN D1S = T
IF FIX1S = T THEN D1S = T
IF FK1S = TTHEN D1S = T
IF FK1S = -4- THEN D1S = T
IF FIXIS = 1-THEN D1S = T
IF FK1S = TTTHEN D1S = T
•PRINT T'
IF D1S = TTHEN
CALL VALVE(PS VS)
STRJi = T'
&|KIZ' = STRT'
EXfTDO
END IF
IFEOF(1) = -1THEN
EXIT DO
END IF
LOOP
STP2' = STPi
DO WHILE EOF(1) <>-1
STPP' = T' "PRIOR TIME
INPUT »1 PS T>
FIX2S ° MIDS(PS I' 1)
-D-THEND2S = -1- -BLANK OUT V DATA
IF FIX2S = fTHEN D2S = T
IF FIX2S = -9- THEN D2S « V
N22
-------
IF FIX2S = -8- THEN 021 = T
IF FIX2S = -S- THEN D2S = '1 -
IF F1X2S = "4- THEN D2S = T
IF FIX2J = 1-THEN D2S = 1'
IF FIX2S = TT THEN D2S = 1-
"0-THEN
STP' = STPPi
EXfTDO
END IF
IFEOF(1) = .1THEN
EXFTOO
END IF
LOOP
IFEOF(1) = -1 THEN
EXIT DO
END IF
FLOW = STP' - STRT'
IF STRTi > STP' THEN
FLOW .86400-STRTi* STP'
END IF
BORTi = STRT21 - STP21
IF BDRT> • STRTi THEN
BDRT'eO
END IF
IFSTP2i>STRT2'THEN
BDRTi = 86400 - STP2' • STRT2'
END IF
TMEF' = TMEFi»(STRT2' • STRTI')
TIMEBD' = TWEED' *(STPi - STP2')
IF COUNT' = 1 THEN
TIMEBD' = FLOW * TMEF'
END IF
COUNT'S 2
STRTI1 = STRT'
PRINT VS • -.
PRINT USING "HHU» M -. STRT'. STP' TWEF'. FLOW. TIMEBD'. BDRT'
PRINT «2. VJ • •
PRINT K. USING •*•**»** • STRT' STP'. TIMEF'. FLOW. TMEBD'. BDRT'
LOOP
END SUB
SUB VALVE (PS. VS)
• CONVERT HEX TO BINARY
FIXJ = MIDJ(PJ 2 1)
IF FIXS = f THEN VS = TJ.O 0"
IF FKS = •£' THEN VS = T).0 Or
IF FIXS = T3- THEN VS = T).0 r
IF FIXS = -Cm THEN VS = T) 0 V
IF FIXS = -B- THEN VS = T) 1 - DFNS
LOCATE 24 1.0
CALL SAVDSK(SH OUTFILES)
OPEN DFNS FOR INPUT AS *1
IF S% = 1 THEN OPEN OUTFILES FOR APPEND AS *2
DO UNTIL EOF(1)
P1S' = 0
P2S' = 0
THMS' = 0
T1S' = 0
T2S' = 0
T3S' = 0
OSC' = O
FOR X = 1 TO 20
INPUT «1.P1« P2' TMM'.TV T2' T3'. OHSC' HEX.TME' INPUT DATA
PIS' = PIS1 *PV
P2S' = P2S' » P2'
THMS' = THMS' •> THM<
T1S' = T1S'*T1'
T2S1 = T2S" » T21
T3S' = T3S'*T3'
OSCS' = OSCS' » OHSC1
IF TME< < OLDTME' THEN
TME' = 86400 »TME'
END IF
OLDTME' = TME'
IFEOF(1) = -1THEN
END
END IF
NEXTX
THMA1 = THMS'/20
T1A' = T1S'/20
T2A' = T2S'/20
T3A' = T3S'/20
OSCA' = OSCS'/20
PRINT P1A1 " P2A' •• THMA' " T1A' " T2A' " T3A' " OSCA' ".TME'
IF S% = 1 THEN
PRINTW P1A' ".P2A'.-- THMA1 "T1A' " T2A' "T3A' " OSCA' " TME'
END IF
LOOP
IFEOF(1) = -t THEN
CLOSE END
END IF
N24
-------
SUB SAVDSK (S% OUTFILES)
WHILE CONS « "C-
LOCATE 14 15 INPUT "SAVE DATA TO DISK fY/N) - SAVS
WHILE SAVS <> TT AND SAVS <> "IT AND SAVS <> "Y" AND SAVS <> V
LOCATE 14. 39 INPUT SAVS
WEND
IF SAVS = TiT OR SAVS = in-THEN S% = 0 EXFTSUB
IF SAVS = -Y- OR SAVS = V THEN S% = 1 ELSE SW = 0
LOCATE 16 15 INPUT "WHICH DRIVE (A.B C )' DRVS
WHILE DRVS <> -A- AND DRVS <> "B AND DRVS <> "C"
LOCATE 16 38 INPUT DRVS
WEND
LOCATE 1615 INPUT -WHAT DATA FILE NAME (OO NOT TYPE EXTENSION) • DFNS
WHILE DFNS = -
LOCATE IB 59 INPUT DFNS
WEND
OUTFILES = DRVS »~V* DFNS ••(XT' DATA FILE-
LOCATE 21 5 PRINT-DATA WILL BE SAVED TO " OUTFILES
LOCATE 23. 5 PRINT "ETURN TO SETUP '. CONS
LOCATE 23. 4O INPUT CONS
IF CONS o X' THEN CLS
WEND
END SUB
N25
-------
APPENDIX N, ATTACHMENT 7, PROGRAM: AVG1-H.BAS
DECLARE SUB SAVDSK (S% OUTFILES)
=>AVG1 BAS
»RMuoas size of analog files by averagno 40 data pomu to 1
CLS
CLOSE
OLDTME' = 0
ERR1 =0
ICHNG = 0
LOCATE 11.15 PRINT "WHICH DATA FILE TO READ (*EXT) •
LOCATE 12.15 INPUT TTYPE DRIVE FILENAME -. DFNS
LOCATE 24 1.0
CALL SAVDSK(SS. OUTFILES)
OPEN DFNS FOR INPUT AS 01
IF SS = 1 THEN OPEN OUTFILES FOR APPEND AS *2
DO UNTIL EOF(1)
P1S' = 0
P2S' = 0
THMS' = 0
T1S' = 0
T2S' = 0
T3S' = 0
FORX = 1TO40
IFEOF(1) = -1 THEN
•X = X(END) * 1 SO NO CHANGE IS REQUIRED
EXFTFOR
END IF
INPUT «1 P1'
IFP1' = P500THEN
ERR1 = 1
INPUT »1. P2S THMS T1S T2S T3S OHSCS HXS TMS.DTES
•X = X(END)« 1. SO NO CHANGE IS REQUIRED
EXIT FOR
END IF
INPUT *1 P2< THM' T1'.T2'.T3' OHSC' NUMS TME' "INPUT DATA
P1S' = P1S'«P1'
P2S' = P2S' « P2'
THMS' = THMS' * THM'
T1S' = T1S'»T1'
T2S' = T2S' » T2'
T3S' = T3S' • T3i
•0-HS SCALE ACCUMULATES THUS TAKE LAST READING
IF TME' < OLDTME' THEN
ICHNG = ICHNG * 1
END IF
OLDTME' = TME'
TMES = ICHNG * 86400 * TME'
NEXTX
P1A' = P1S'/(X-1)
P2A' = P2S'/(X- 1)
THMA'=THMS'/(X-1)
T1A' = T1S'/(X-1)
T2A' = T2S'/(X-1)
T3A' = T3S'/(X-1)
PRINT USING •**• * ' P1A- P2A1 THMA' T1A' T2A' T3A' OHSC'
PRINT NUMS - •
PRINT USING "MM***M- TMES
IF ERR1 = 1 THEN
P1S = -P500-
PRINT" PIS ' ' P2S ' ' THMS ' " T1S ' ' T2S '. '. T3S " ~ OHSCS ' -. HXS '. • TMS '. '. OTES
END IF
N26
-------
If S* = 1 THEN
PRINT *2 USING •»»»« ' P1A' P2A' THMA' T1A' T2A' T3A' OHSC'
PRINT « NUMS ••
PRINT 02 USING ' »»0«»»n tat', TMES
IF ERRI = 1 THEN
n?,^*2 "" P1* " " K* ' " ™M$ " • T1$ • • T2i • • T3$ • '. OHSCS. • • HXS -. • TIMS ' • DTES
cNu IF
END IF
IF EOF(1) =-1 THEN
CLOSE END
END IF
LOOP
SUBSAVDSKfS* OUTFILES)
WHILE CONS o -C-
LOCATE 1415 INPUT "SAVE DATA TO DISK (Y/N)". SAVS
WHILE SAVS <> -V AND SAVS <> ~n~ AND SAVS » -V AND SAVS <> V
LOCATE 14 39 INPUT SAVS
WEND
IF SAVS = TT OR SAVS = TV THEN S% = 0 EXIT SUB
IF SAVS = T OR SAVS = V THEN SK = 1 ELSE SS = 0
LOCATE 16.15 INPUT -WHICH DRIVE (A.B.C ) * DRVS
WHILE DRVS <> 'A- AND DRVS <> "V AND DRVS <> f
LOCATE 16. 38 INPUT DRVS
WEND
LOCATE 18. 15 INPUT "WHAT DATA FILE NAME (DO NOT TYPE EXTENSION) - OFNS
WHILE DFNS = ™"
LOCATE 18. 59 INPUT DFNS
WEND
OUTFILES- DRVS *-\'» OFNS •-RNA" DATA FILE-
LOCATE 21.5 PRINT TWVTA WILL BE SAVED TO '. OUTFILES
LOCATE 23. 5 PRINT -ONTINUE OR ETURN TO SETUP - CONS
LOCATE 23 40- INPUT CONS
IF CONS <> "C-THEN CLS
WEND
END SUB
N27
-------
APPENDIX N, ATTACHMENT 8, PROGRAM: V-AVG1.DOC
DECLARE SUB SAVDSK (S« OUTFILES)
AVG1 BAS AvwapvakieerVraMes PSCO. P90. imud T1. T2 T3
oner • tpacfma tnw franw
CIS
CLOSE
LOCATE 11.15 PRINT "WHICH DATA FILE TO READ (*£XT) *
LOCATE 12. IS WPUT TJVPE DRIVE FILENAME - DFNS
LOCATE 24. 1.0
CALL SAVDSK(S%. OUTFILES)
CLS
OPEN DFNS FOR INPUT AS «1
IF S% • 1 THEN OPEN OUTFILES FOR APPEND AS K
LOCATE 16. 15 INPUT INPUT BEGINNING TME (SECONDS) * TM
LOCATE 18. IS INPUT INPUT ENDING TME (SECONDS) -. TFNL
FU • TILE NAME*
PIS-TSW
THMS-TMUD-
T1S-T1-
T2» = TT
TSS-TT
DELTS =
PIS) • 0
P2SI«0
THMSI-0
T1S> • 0
TZS"0
T3SI«0
COUNT «0
DOUMTtLEOF(l)
DOVWILEEOF(1)o.1
MPUT*1. Pit P2I THM'. Til T2'. T3i. OHSCL NUMS. TME' 'INPUT DATA
WMILE TMEI >= TIN AND TME' « TFNL
PIS' « PIS1* PI!
P2S' • P2S' • P2'
THMSIcT>WS'*THMi
T1S' = T1SI»T1I
T2S' = T2S' • T2'
T3S'«T3S'»T3'
COUNT • COUNT • 1
TSTP-TME'
IF EOF(1) c .1 THEN
EXIT DO
END IF
INPUT «1. PV. P2I. TMMi. TV. T2'. T3I. OHSCI. NUMS TMEI 'INPUT DATA
WEND
IF TMEI > TFNL THEN
EXIT DO
END IF
LOOP
PI A" -PIS' /COUNT
P2AI = P2SI/ COUNT
THMAI = THMSI / COUNT
T1A' «T1SI /COUNT
T2A' = T2S'/ COUNT
T3Ai = T3SI/ COUNT
DELT = TFNL -TIN
PRINT DFNS •-.
PRINT USING •»•» • - P1AI. P2A'. THMA'. T1A'. T2A'. T3A'. DELT.
PRINT USING * MMM* ftT TSTP'
PRINT FILS. '. '. P1S '. -. P2S '. •: THMS. '. I T1S '. -. T2S. '. *. T3S. '. -. OELTS. -. -. TMS
N28
-------
IF S% • 1 THEN
PRINT *2 DFNS "
PRINT n. USING •»•» • ~ P1A' P2A1 TKMA< T1A!. T2A" T3A' DELT'
PRINT n USING • »»••»«! «r~ TSTP'
END IF
IFEOF(1)>-1THEN
IF S% > 1 THEN
PRINT f2 FILS •. •• P1J. ". -. P2S • - THMS -. •• T1$ • • T2S • - T3S - - DELTJ • • TMS
END IF
CLOSE STOP
END IF
LOCATE 24 15 PRINT THERE WILL BE A 20 SECOND PAUSE1"
SLEEP 20
CLS
LOCATE 12 15 MPUT "DO YOU WANT TO RUN ANOTHER SET OF TMES ON THIS FILE* (Y/N) - AN*
IFANt-TTTHEN
IF SK • 1 THEN
PRINT n. FILS '. - P1$ -. -. P2$. -. - THMS -. '. T1J -. - T2J • - T3S. • ~ DELTJ. '. ~nu
END IF
CLOSE STOP
END IF
LOCATE 14. IS PRMT -TIN MUST BE > - TMEI
LOCATE 16.15 HPUT TNPUT BEGINNING TIME (SECONDS) -. TIN
LOCATE 18.15 MPUT INPUT ENDING TME (SECONDS) -. TFM.
PIS'-O
P2S»0
THMS'«0
T1SI-0
T2SI-0
TSSI'O
COUNT-0
LOOP
SUB SAVDSK (S«. OUTFILES)
WHILE CONS o-C-
LOCATE 14. IS MPUT "SAVE DATA TO DISK (Y/N)'. SAVJ
WMILE SAVS o tT AND SAV» o tr AND SAVJ o -VAND SAVJ o V
LOCATE 14. » MPUT SAVS
WEND
IF SAVS • TT OR SAVS = If THEN S« • & EXIT SUB
IF SAVS « -T OR SAVS - V THEN Stt = 1 ELSE S« • 0
LOCATE 16.15 MPUT 'WHICH DRIVE (A.B.C .)'. DRVJ
WHILE DRV1 o-A-AND DRVS o-V AND DRVS o T-
LOCATE 16. 38 MPUT DRVJ
WEND
LOCATE 18 IS MPUT -WHAT DATA FILE NAME (DO NOT TYPE EXTENSION) ~. DFNS
WHILE DFNS*-
LOCATE 18. 59 MPUT DFNS
WEND
OmTILE»« DRVJ »'\'» OFNS «-.AVG-' DATA FILE-
LOCATE 21.5 PRMT TJATA WILL BE SAVED TO ". OUTFILES
LOCATE 23 5 PRMT -ONTINUE OR ETURN TO SETUP * CONS
LOCATE 23 40- INPUT CONS
IF CONS o f THEN CLS
WEND
END SUB
N29
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