WITSML- Catalog of Value Constrainted Types. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. Activity codes. The list of standard values is contained in the WITSML enumValues.xml file. The north direction as defined by the magnetic north pole at the time of the measurement. The magnetic north pole is the direction that a magnet will point to when freely rotating. The north direction is defined by the coordinate grid in the projection coordinate system. The north direction as defined by the true north pole. The true north pole is an average of the actual measured north axis, which is the axis of rotation of the earth. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. A list of binary representations for elements of aggregates which may be Base64-encoded (e. g. elements of well log array traces, or multiplexed frames of similar-typed well log traces) as described in "XML Schema Part 2: Datatypes", 3.2.16 base64binary [http://www.w3.org/TR/xmlschema-2/#base4Binary]] and in "Multipurpose Internet Mail Extensions (MIME) Part One: Format of Internet Message Bodies" (IETF RFC 2045) [ http://www.ietf.org/rfc/rfc2045.txt ]. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent a classification of a drill bit based on its reason for being declared inoperable, as originally defined by the IADC. Broken Cone Broken teeth/cutters Balled Up Cracked Cone Cone Dragged Cone Interference Cored Chipped Teeth Erosion Flat Crested Wear Heat Checking Junk Damage Lost Nozzle Lost Nozzle Lost Teeth/Cutters No Dull/No Other Wear Off-Center Wear Pinched Bit Plugged Nozzle Rounded Gauge Ring Out Shirttail Damage Self-Sharpening Wear Tracking WashOut on Bit Worn Teeth/Cutters The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the reason for pulling a drill bit from the wellbore, as originally defined by the IADC. Change Bottom Hole Assembly Condition Mud Core Point Downhole Motor Failure Drill Plug Drill Stem Test Downhole Tool Failure Formation Change Hole Problems Hours on Bit Run Logs Pump Pressure Penetration Rate Rig Repairs Total Depth/Casing Depth Torque Twist Off Weather Conditions The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the type of drill/core bit. Diamond bit Diamond core bit Insert roller cone bit polycrystalline diamond compact fixed cutter bit polycrystalline diamond compact core bit Milled tooth roller cone bit The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the type of Box/Pin configuration. Bottom box, top box Bottom box, top pin Bottom pin top box Bottom pin The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the position of a connection. The connection is the same at both ends of the component This connection is only at the bottom of the component This connection is only at the top of the component The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent method used to direct the deviation of the trajectory. Rotary Steerable System that deviates a wellbore by tilting the bit to point it in the desired direction. Rotary Steerable System that deviates a wellbore by inducing a side force to push the bit in the desired direction. These values represent the type of drilling derrick. 2 stand capacity derrick 4 stand capacity derrick Slant derrick 3 stand capacity derrick The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the type of work string drive (rotary system). Coiled tubing rig Kelly drive system Top Drive The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The type of local or permanent reference datum for vertical gravity based (i.e., elevation and vertical depth) and measured depth coordinates within the context of a well. This list includes local points (e.g., kelly bushing) used as a datum and vertical reference datums (e.g., mean sea level). casing flange: A flange affixed to the top of the casing string used to attach production equipment. crown valve derrick floor ground level kelly bushing rotary bushing rotary table sea floor Lowest Astronomical Tide. The lowest tide level over the duration of the National Tidal Datum Epoch (19 years). Mean Sea Level - A tidal datum. The arithmetic mean of hourly heights observed over the National Tidal Datum Epoch (19 years). Mean Higher High Water - A tidal datum. The average of the higher high water height of each tidal day observed over the National Tidal Datum Epoch (19 years). Mean High Water - A tidal datum. The average of all the high water heights observed over the National Tidal Datum Epoch (19 years). Mean Lower Low Water - A tidal datum. The average of the lower low water height of each tidal day observed over the National Tidal Datum Epoch (19 years ). Mean Low Water - A tidal datum. The average of all the low water heights observed over the National Tidal Datum Epoch (19 years). Mean Tide Level - A tidal datum. The arithmetic mean of mean high water and mean low water. Same as half-tide level. kickoff point The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the type of ellipsoid (spheroid) defining geographic or planar coordinates. Australian Old Modified Airy Airy 1830 Airy 1849 Australian National Same as KAU63 and SA69 Bessel Modified Bessel - NGO 1948 Bessel - RT90 Bessel 1841 Bessel 1841 for Namibia BOGOTA (International 1924) Clarke 1858 Clarke 1858-1 Clarke 1866 Clarke 1866 for Michigan Clarke 1880 Clarke 1880 variation A Clarke 1880 variation B Clarke 1880 IGN Clarke 1880 for Jamaica Clarke 1880 for Merchich Clarke 1880 for Palestine CAMPO INCH (International 1924) Danish DELAMBRE 1810 ED50 (International 1924) EGYPT07 (Helmert 1906) Everest 1830 - Indian Everest 1948 Everest 1956 Everest 1969 Everest Brunei Modified Everest Everest Pakistan Everest 1830 (modified) Timbalai Everest - Timbali "Fischer 1960 aka ""Mercury""" Fischer 1960 Modified "Fischer 1968 aka ""Modified Mercury""" "Modified Fischer 1960 aka ""South Asia""" GDA94 - Australia Geodetic Reference System 1967 Geodetic Reference System 1980 Hayford 1909 Heiskanen 1929 Helmert 1906 Helmert 1907 Hough 1956 IAG 75 INDIAN75 (Everest 1930) INDO74 (Indonesian 1974) International 1924 IUGG 1967 IUGG 1975 Jeffreys 1948 Kaula 1963 Same as AUST_NAT and SA69 Krassovsky MERIT83 NAD27 (Clarke 1866) NAHRAN (Clarke 1880) New International 1967 NWL 10D NWL 9D OSGB36 (Airy 1830) OSU86F OSU91A Plessis 1817 PSAD56 (International 1924) Pointe Noire 1948 South American 1969 Sphere of radius 6370997 Struve 1860 Walbeck War Office 1924 World Geodetic System 1960 World Geodetic System 1966 World Geodetic System 1972 World Geodetic System 1984 The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The mode of a Distributed Temperature Survey (DTS) fiber. A single, narrow, core of constant refractive index, surrounded by glass cladding. The core diameter is comparable to a wave length of the light (about 5 um). The core has a graded refractive index. The core is generally about 50um in diameter. The fiber mode is neither singlemode or multimode. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the type of geodetic datum. The source (except for "none", "unknown" and "UserDefined") of the values and the descriptions is Geoshare V13. Adindian ellipsoid=CL80 region="Sudan, Ethiopia" ARC 1950 ellipsoid=CL80B region="Southern Africa" Australian ellipsoid=GRS67 region="Australia Geodetic" Camp Area Astro ellipsoid=INT24 region=Antarctica Chau Astro ellipsoid=INT24 region=Paraguay Corrego Alegre ellipsoid=INT24 region=INT24 European 1950 ellipsoid=INT24 region="Europe, Middle East, North Africa" European 1987 ellipsoid=INT24 region="Europe, Middle East, North Africa" Ireland 1965 ellipsoid=AIRY_MOD region=Ireland Geodetic Datum 1949 ellipsoid=INT24 region="New Zealand" Ghana ellipsoid=WAR24 region=Ghana Guam 1963 ellipsoid=CL66 region="Marianas Islands" Hjorsey 1955 ellipsoid=INT24 region=Iceland Hu-Tzu-Shan ellipsoid=INT24 region=Taiwan Campo Inchauspe ellipsoid=INT24 region=Argentina Indian 'Kalimpur' ellipsoid=EVER region=India Indian 'Kalimpur' ellipsoid=INT24 region=India Indonesia 1974 ellipsoid=GRS67 region=Indonesia Liberia 1964 ellipsoid=CL80 region=Liberia Luzon ellipsoid=CL66 region=Philippines Merchich ellipsoid=CL80A region=Morocco North American 'Meades Ranch' ellipsoid=CL66 region="North America" North American Datum of 1983 ellipsoid=GRS80 region="Canada, Cuba, U.S., Caribbean" Nigeria ellipsoid=CL80 region=Nigeria Naparima ellipsoid=INT24 region="Trinidad and Tobago" Ordnance Survey of Great Britain 1936 ellipsoid=AIRY region="Great Britain, Northern Ireland" European 'Pelmert Tower, Potsdam' ellipsoid=INT24 region="Most of Eurasia, Africa" Russian 'Pulkovo' ellipsoid=BESS41 Russian 'Pulkovo' ellipsoid=KRSV Qornoq ellipsoid=INT24 region=Greenland Provisional South American, 1956 ellipsoid=INT24 region="Bolivia, Chile, Colombia, Ecuador, Peru, Venezuela, the Guianas" Sierra Leone 1960 ellipsoid=CL80 region="Sierra Leone" Tananarive (Antananarivo) Obsv. 1925T ellipsoid=INT24 region="Malagasy Republic" Tokyo ellipsoid=BESS41 region=Japan Datum defined elsewhere Voirol ellipsoid=CL80 region="Algeria, Tunisia" World Geodetic System 1972 ellipsoid=WGS72 World Geodetic System 1984 ellipsoid=WGS84 region="Sino-Soviet Bloc, SW Asia, Hydrographic, Aeronautical" Yacare ellipsoid=INT24 region=Uruguay The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. Northern hemisphere. Southern hemisphere. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the state of a WITSML object. Actual data measured or entered at the well site. Model data used for "what if" calculations. A planned object. That is, one which is expected to be executed in the future. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The type of Distributed Temperature Survey (DTS) fiber point. A point at which a fiber is physically, and semi-permanently, connected to another length of fiber. A point at which a cable connector is installed, which allows the fiber to be connected to another instrument or fiber length. The end of the fiber. If a U-geometry is used, and a connector is at both ends, the connector classification should be used rather than the end of fiber classification. The deepest point of the installed fiber in a well. This is a valid value for fiber installations that do NOT turn around at the bottom (J- and U-type installations). The point in the turn-around-sub at which measured depth stops increasing and begins decreasing. This is a valid value for fiber installations of the J- and U- type only. The start of the fiber. If appropriate, the connector classification should be used instead of this classification. The point on the fiber at which it enters the oven. The point on the fiber at which it exits the oven. The oven exit point should be closer to the wellbore than the oven entry point. A downhole point on the fiber at which a gauge is attached. The connector between the laser head and the optical fiber. The oven within or near the DTS instrument box which maintains a length of fiber at a reference temperature. Container in which ends of lengths of fiber are joined. The device at which a fiber originating at the instrument box is joined to a fiber installed in a wellbore. This is a recommended location at which LengthAlongFiber and measuredDepth in the wellbore are correlated The device at the base of the wellhead to which the production tubing is attached. This is a recommended location at which LengthAlongFiber and measuredDepth in the wellbore are correlated. The top-most point at which the fiber intersects the PBR (polished bore receptacle). For J- and U- installations, on the upward portion of the fiber, this is the point at which it leaves the pbf. The top of the electrical submersible pump (ESP). This is the minimum measured depth point of the pump. The base of the electrical submersible pump (ESP). This is the maximum measured depth point of the pump. Temperature measuring device at the wellhead independent of the optic fiber sensor. The point which is the minimum measured depth of a completion zone. The point which is the maximum measured depth of a completion zone. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. Specifies the source of lithology information. The lithology has one overall interpretation based on several sources such as logs and cuttings or cores. The lithology as based on a visual inspection of the core. A percentage is commonly assigned to each portion of the lithology. The lithology as based on a visual inspection of the cuttings. A percentage is commonly assigned to each portion of the lithology. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The type of lithology. The list of standard values is contained in the WITSML enumValues.xml file. The endcoding allowed in a realtime channel value or log curve value. Date with time data value. Double precision floating point value. Long integer data value. Character string data. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the direction of movement within a wellbore. Log items are in order of decreasing index values (e.g. wireline log logging while pulling out of hole) Log items are in order of increasing index values (e.g. increasing depths or times) The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the type of data used as an index value for a log. Log is indexed on date with time. Log is indexed on time. Log is indexed on length (not a depth). Log index is a measured depth index. Log index is a vertical depth depth index . Any other index type for a log. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The data were read from a realtime sensor stream. The data are synthetic. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The source (except for "CH density porosity", "CH neutron porosity", "OH density porosity" and "OH neutron porosity") of the values and the descriptions is the POSC V2.2 "well log trace class" standard instance values which are documented as "A classification of well log traces based on specification of a range of characteristics. Traces may be classed according to the type of physical characteristic they are meant to measure." Output from an accelerometer on a logging tool. A well log which uses an acoustic device to measure hole diameter. The signal measured by an acoustic device at the location of casing collars and other features (e.g., perforations). Seismic velocity multiplied by density. Porosity calculated from an acoustic log. The velocity of an acoustic wave. The time it takes for an acoustic wave to traverse a fixed distance of a given material or matrix. In this case the material or matrix is a specific, zero porosity rock, e.g. sandstone, limestone or dolomite. The time it takes for an acoustic wave to traverse a fixed distance. Any measurement of the maximum departure of a wave from an average value. The extent of departure of an acoustic wave measured from the mean position. The extent of departure of an electromagnetic wave measured from the mean position. The ratio of two amplitudes. A particular extent of space or surface. The amount of reduction in the amplitude of a wave. The amount of reduction in the amplitude of an acoustic wave. The amount of reduction in the amplitude of an electromagnetic wave. A general classification for measurements which are very specialized and not normally accessed by petrophysicists. The pore volume of a rock averaged using various well log or core porosity measurements. In the horizontal plane, it is the clockwise angle of departure from magnetic north (while looking down hole). A trace which has been corrected for the effects of barite in the borehole fluid. A trace which has been corrected for bed thickness effects. The diameter of the drill bit used to drill the hole. A well log trace which has been edited to reflect sharp bed boundaries. The trace has a square wave appearance. A trace which has been corrected for the effects of the borehole environment; e.g., borehole size. Deprecated. Use mud composition correction. A trace which has been corrected for the effects of borehole fluid; e.g., a mud cake correction. A trace which has been corrected for the effects of borehole size. A trace which has been corrected for the effects of bromide in the borehole fluid. The relative compressibility of a material. The measured density of a rock with the pore volume filled with fluid. The pore fluid is generally assumed to be water. A quantity per unit volume. The quantity of gas present in a unit volume of rock. The product of gas saturation and total porosity. The quantity of hydrocarbon present in a unit volume of rock. The product of hydrocarbon saturation and total porosity. The quantity of oil present in a unit volume of rock. The product of oil saturation and total porosity. The quantity of formation water present in a unit volume of rock. The product of water saturation and total porosity. The ratio of the Carbon measurement to the Oxygen measurement. A well log used to record hole diameter (open or cased). A trace which has been corrected for the effects of being recorded in a cased hole; e.g., corrected for casing weight and thickness. The signal measured by a device at the location of casing collars and other features (e.g., perforations). A trace which has been corrected for the effects of casing; this includes things such as casing weight, thickness and diameter. A trace which has been corrected for the effects of casing diameter. Any of the measurements made for the purpose of determining the properties of the well casing. A trace which has been corrected for the effects of casing thickness. A trace which has been corrected for the effects of casing weight. A trace which has been corrected for the effects of the cement surrounding the casing; this includes cement thickness, density and type. A trace which has been corrected for the effects of cement density. Any of the measurements made to determine the presence and quality of the cement bond to casing or to formation. A trace which has been corrected for the effects of cement thickness. A trace which has been corrected for the effects of the type of cement used. Porosity calculated from the bulk density measurement of a cased hole density log using a dolomite matrix density. Porosity calculated from a cased hole neutron log using a dolomite matrix. Porosity calculated from the bulk density measurement of a cased hole density log using a limestone matrix density. Porosity calculated from a cased hole neutron log using a limestone matrix. Porosity calculated from the bulk density measurement of a cased hole density log using a sandstone matrix density. Porosity calculated from an open hole neutron log using a sandstone matrix. Porosity calculated from a compressional wave acoustic log using a dolomite matrix. Porosity calculated from a compressional wave acoustic log using a limestone matrix The time it takes for a compressional acoustic wave to traverse a fixed distance of a given material or matrix. In this case the material or matrix is a specific, zero porosity rock, e.g. sandstone, limestone or dolomite. Porosity calculated from a compressional wave acoustic log using a sandstone matrix. The time it takes for a compressional acoustic wave to traverse a fixed distance. The property of a medium (solid or fluid) which allows the medium to conduct a form of energy; e.g., electrical conductivity or thermal conductivity. Conductivity calculated from the attenuation of an electromagnetic wave. Generally recorded from a LWD resistivity tool. Conductivity calculated from the phase shift of an electromagnetic wave. Generally recorded from a LWD resistivity tool. The conductivity of the water entrapped in the interstices of the rock. The resistivity of the water entrapped in the interstices of the rock. Porosity from a measurement made on a conventional core. The density of a rock matrix measured on a core sample. The permeability derived from a core. Porosity from a core measurement. A trace which has had corrections applied; e.g. environmental corrections. The rate of occurrences; e.g. the far counts from a density tool.. The ratio of two count rates. The pore volume of a rock calculated from cross plotting two or more well log porosity measurements. The time it takes for a population to decay, generally expressed as a half life. The conductivity which represents a measurement made several feet into the formation; generally considered a measurement of the undisturbed formation. The conductivity, measured by an induction log, which represents a measurement made several feet into the formation; generally considered a measurement of the undisturbed formation. The resistivity, measured by an induction log, which represents a measurement made several feet into the formation; generally considered a measurement of the undisturbed formation. The conductivity, measured by a laterolog, which represents a measurement made several feet into the formation; generally considered a measurement of the undisturbed formation. The resistivity, measured by a laterolog, which represents a measurement made several feet into the formation; generally considered a measurement of the undisturbed formation. The resistivity which represents a measurement made several feet into the formation; generally considered a measurement of the undisturbed formation. Mass per unit Volume - well logging units are usually gm/cc. Porosity calculated using the bulk density measurement from a density log. The distance to a point in a wellbore. The process of depth correcting a trace by depth matching it to a reference trace. The depth calculated from velocity information. Departure of a borehole from vertical. Also, the angle measured between the tool axis and vertical. Relative permittivity. A trace which has been corrected for the effects of diffusion. The angle that a structural surface, e.g. a bedding or fault plane, makes with the horizontal, measured perpendicular to the strike of the structure. Any of a number of measurements produced by a tool designed to measure formation dip and borehole characteristics through direct and indirect measurements. The conductivity, measured by a dipmeter, which represents a measurement made approximately one to two feet into the formation; generally considered to measure the formation where it contains fluids which are comprised primarily of mud filtrate. The resistivity, measured by a dipmeter, which represents a measurement made approximately one to two feet into the formation; generally considered to measure the formation where it contains fluids which are comprised primarily of mud filtrate. Porosity calculated from an acoustic log using a dolomite matrix. Porosity calculated from the bulk density measurement of a density log using a dolomite matrix density. Porosity calculated from a neutron log using a dolomite matrix. A well log trace which has been corrected or adjusted through an editing process. The interconnected pore volume occupied by free fluids. The flow of electric charge. The difference in electrical energy between two systems. The time it takes for an electromagnetic wave to traverse a fixed distance of a given material or matrix. In this case the material or matrix is a specific, zero porosity rock, e.g. sandstone, limestone or dolomite. The time it takes for an electromagnetic wave to traverse a fixed distance. The elemental composition, generally in weight percent, of a formation as calculated from information obtained from a geochemical logging pass; e.g., weight percent of Al, Si, Ca, Fe, etc. The ratio of two different elemental measurements; e.g. K/U. A well log trace which has been filtered to improve its value; e.g. inverse filtering for better resolution. A well log trace which has had a filter applied to it. A logging tool to measure the rate and/or direction of fluid flow in a wellbore. The quantity per unit volume of fluid. The velocity of a flowing fluid. The amount of a fluid resistance to flow. The conductivity of the zone immediately behind the mud cake and which is considered to be flushed by mud filtrate, i.e., it is considered to have all mobile formation fluids displaced from it. The resistivity of the zone immediately behind the mud cake and which is considered to be flushed by mud filtrate, i.e., it is considered to have all mobile formation fluids displaced from it. The fraction or percentage of pore volume of rock occupied by drilling mud or mud filtrate in the flushed zone. Energy exerted or brought to bear. A trace which has been corrected for formation density effects. A trace which has been corrected for formation properties; e.g., salinity. A trace which has been corrected for the salinity effects from the water in the formation. A trace which has been corrected for formation saturation effects. A trace which has been corrected for the effects of the hydrocarbon formation volume factor. A trace which has been corrected for the effects of the density of the formation water. A trace which has been corrected for water saturation effects. The percent of the bulk volume occupied by fluids which are free to flow as measured by the nuclear magnetism log. A trace which has been corrected for the effects of friction. The measurement of naturally occurring Gamma Ray radiation being released by radioisotopes in clay or other minerals in the formation. The measurement of the naturally occurring gamma radiation less the radiation attributed to uranium. The fraction or percentage of pore volume of rock occupied by gas. The measurement of the average density of fluids in a wellbore. A measurement of the conductivity of the formation, by a high frequency electromagnetic tool, within the first few cubic inches of the borehole wall. High frequency electromagnetic measurements, e.g. from a dielectric logging tool. Porosity calculated using a high frequency electromagnetic measurement as input. The amount of change in the phase of a high frequency electromagnetic wave. A measurement of the resistivity of the formation, by a high frequency electromagnetic tool, within the first few cubic inches of the borehole wall. A trace which has been corrected for the effects of hydrocarbons. A trace which has been corrected for the effects of hydrocarbon density. A trace which has been corrected for the effects of hydrocarbon gravity. The fraction or percentage of pore volume of rock occupied by hydrocarbon. A trace which has been corrected for the effects of hydrocarbon viscosity. The likeness of an object produced by an electrical device. A variable in a well log interpretation equation. A trace which has been corrected for the effects of iron in the borehole fluid. A well log trace which has had two or more runs spliced together to make a single trace. A trace which has been corrected for the effects of KCl in the borehole fluid. A measured distance or dimension. Porosity calculated from an acoustic log using a limestone matrix. Porosity calculated from the bulk density measurement of a density log using a limestone matrix density. Porosity calculated from a neutron log using a limestone matrix. A trace which has been corrected for lithology effects. The permeability derived from a well log. The density of a rock matrix used with, or derived from, the bulk density from a well log. The matrix is assumed to have zero porosity. The signal measured by a magnetic device at the location of casing collars and other features (e.g., perforations). The density of a rock matrix. In this case, the matrix is assumed to have zero porosity. The time it takes for an electromagnetic or acoustic wave to traverse a fixed distance of a given material or matrix. In this case the material or matrix is a specific, zero porosity rock, e.g. sandstone, limestone or dolomite. The distance measured along the path of a wellbore. A well log which uses a mechanical device to measure hole diameter. The signal measured by a mechanical device at the location of casing collars and other features (e.g., perforations). The conductivity which represents a measurement made approximately two to three feet into the formation; generally considered to measure the formation where it contain fluids which are a mixture of mud filtrate, connate water and possibly hydrocarbons. The conductivity, made by an induction log, which represents a measurement made approximately two to three feet into the formation. The resistivity, made by an induction log, which represents a measurement made approximately two to three feet into the formation. The conductivity, measured by a laterolog, which represents a measurement made approximately two to three feet into the formation. The resistivity, measured by a laterolog, which represents a measurement made approximately two to three feet into the formation. The resistivity which represents a measurement made approximately two to three feet into the formation; generally considered to measure the formation where it contain fluids which are a mixture of mud filtrate, connate water and possibly hydrocarbons. A measurement of the conductivity of the formation within the first few cubic inches of the borehole wall. A conductivity measurement made by a micro log tool which measures within the first few cubic inches of the borehole wall. A resistivity measurement made by a micro log tool which measures within the first few cubic inches of the borehole wall. A measurement of the conductivity of the formation, by a laterolog, within the first few cubic inches of the borehole wall. A measurement of the resistivity of the formation, by a laterolog, within the first few cubic inches of the borehole wall. A conductivity measurement made by a micro log tool which measures within the first few cubic inches of the borehole wall. A resistivity measurement made by a micro log tool which measures within the first few cubic inches of the borehole wall. A measurement of the resistivity of the formation within the first few cubic inches of the borehole wall. A measurement of the conductivity of the formation, by a spherically focused tool, within the first few cubic inches of the borehole wall. A measurement of the resistivity of the formation, by a spherically focused tool, within the first few cubic inches of the borehole wall. The mineral composition, generally in weight percent, of a formation as calculated from elemental information obtained from a geochemical logging pass; e.g., weight percent of dolomite, calcite, illite, quartzite, etc. The conductivity of the filter cake, the residue deposited on the borehole wall as mud loses filtrate into porous and permeable rock. A trace which has been corrected for the effects of mud cake; e.g., mud cake thickness and/or density. A trace which has been corrected for the effects of mud cake density. The resistivity of the filter cake, the residue deposited on the borehole wall as mud loses filtrate into porous and permeable rock. A trace which has been corrected for the effects of mud cake resistivity. A trace which has been corrected for the effects of mud cake thickness. A trace which has been corrected for the effects of borehole fluid composition; e.g., a correction for KCl in the borehole fluid. The conductivity of the continuous phase liquid used for the drilling of the well. The conductivity of the effluent of the continuous phase liquid of the drilling mud which permeates porous and permeable rock. A trace which has been corrected for the effects of mud filtrate. This includes things such as filtrate salinity. A trace which has been corrected for the effects of mud filtrate density. The resistivity of the effluent of the continuous phase liquid of the drilling mud which permeates porous and permeable rock. A trace which has been corrected for the effects of mud filtrate resistivity. A trace which has been corrected for the effects of mud filtrate salinity. The resistivity of the continuous phase liquid used for the drilling of the well. A trace which has been corrected for the effects of salinity in the borehole fluid. A trace which has been corrected for the effects of the viscosity of the borehole fluid. A trace which has been corrected for the effects of weighting the borehole fluid. The time it takes for a neutron population to die away to half value. Porosity from a neutron log. A well log which uses a nuclear device to measure hole diameter. The decay time of a nuclear magnetic signal. The permeability derived from a nuclear magnetism log. Porosity calculated using the measurements from a nuclear magnetism logging pass. Porosity calculated from the bulk density measurement of an open hole density log using a dolomite matrix density. Porosity calculated from an open hole neutron log using a dolomite matrix. Porosity calculated from the bulk density measurement of an open hole density log using a limestone matrix density. Porosity calculated from an open hole neutron log using a limestone matrix. Porosity calculated from the bulk density measurement of an open hole density log using a sandstone matrix density. Porosity calculated from an open hole neutron log using a sandstone matrix. A trace which has been corrected for the effects of oil based borehole fluid. The fraction or percentage of pore volume of rock occupied by oil. The procedure for introducing holes through casing into a formation so that formation fluids can enter into the casing. The permeability of the surrounding formation. A change or variation according to a harmonic law from a standard position or instant of starting. The effect measured by the density log and produced by the process of a photon colliding with an atom, and then being completely absorbed and its total energy used to eject one of the orbital electrons from those surrounding the nucleus. The correction that is to be made to the photoelectric absorption curve. A trace which has been corrected for various physical measurement effects; e.g. spreading loss. An angle formed by two intersecting lines. The total pore volume occupied by fluid in a rock. Includes isolated nonconnecting pores and volume occupied by absorbed, immobile fluid. A trace which has been corrected for porosity effects. The measurement of gamma radiation emitted by potassium. The force or thrust exerted upon a surface divided by the area of the surface. A trace which has been corrected for the effects of pressure in the borehole. A well log trace which has been processed in some way; e.g., depth adjusted or environmentally corrected. Porosity calculated from a pulsed neutron log. Degree of excellence. A relationship between two values usually expressed as a fraction. A well log trace which has not had any processing. In other words, a trace which has not been depth adjusted or environmentally corrected. While looking down hole, it is the clockwise angle from the upper side of the sonde to the reference pad or electrode. The property measuring the resistance to flow of an electrical current. A trace which has been corrected for resistivity factor effects. Resistivity calculated from the attenuation of an electromagnetic wave. Generally recorded from a LWD resistivity tool. Resistivity calculated from the phase shift of an electromagnetic wave. Generally recorded from a LWD resistivity tool. The amount of change in the phase of an electrical wave. The ratio of two resistivity values. The concentration of ions in solution. To take a sample of or from something. Porosity calculated from an acoustic log using a sandstone matrix. Porosity calculated from the bulk density measurement of a density log using a sandstone matrix density. Porosity calculated from a neutron log using a sandstone matrix. The fraction or percentage of the pore volume of a rock. An estimate of the amount of shale present in the formation. Frequently calculated from a gamma ray or SP curve. The conductivity which represents a measurement made approximately one to two feet into the formation; generally considered to measure the formation where it contains fluids which are comprised primarily of mud filtrate. The conductivity, measured by an induction log, which represents a measurement made approximately one to two feet into the formation; generally considered to measure the formation where it contains fluids which are comprised primarily of mud filtrate. The resistivity, measured by an induction log, which represents a measurement made approximately one to two feet into the formation; generally considered to measure the formation where it contains fluids which are comprised primarily of mud filtrate. The conductivity, measured by a laterolog, which represents a measurement made approximately one to two feet into the formation; generally considered to measure the formation where it contains fluids which are comprised primarily of mud filtrate. The resistivity, measured by a laterolog, which represents a measurement made approximately one to two feet into the formation; generally considered to measure the formation where it contains fluids which are comprised primarily of mud filtrate. The resistivity which represents a measurement made approximately one to two feet into the formation; generally considered to measure the formation where it contains fluids which are comprised primarily of mud filtrate. Porosity calculated from a shear wave acoustic log using a dolomite matrix. Porosity calculated from a shear wave acoustic log using a limestone matrix. The time it takes for a shear acoustic wave to traverse a fixed distance of a given material or matrix. In this case the material or matrix is a specific, zero porosity rock, e.g. sandstone, limestone or dolomite. Porosity calculated from a shear wave acoustic log using a sandstone matrix. The time it takes for a shear acoustic wave to traverse a fixed distance. A well log trace which has had its original values shifted by some factor; e.g., added or multiplied by a constant. Porosity from a measurement made on a sidewall core. The macroscopic capture cross section, i.e. the effective cross-sectional area per unit volume for the capture of neutrons. The macroscopic capture cross section, i.e. the effective cross-sectional area per unit volume, of the formation for the capture of neutrons. The macroscopic capture cross section, i.e. the effective cross-sectional area per unit volume, of gas for the capture of neutrons. The macroscopic capture cross section, i.e. the effective cross-sectional area per unit volume, of hydrocarbon for the capture of neutrons. The macroscopic capture cross section, i.e. the effective cross-sectional area per unit volume, of the rock matrix for the capture of neutrons. The macroscopic capture cross section, i.e. the effective cross-sectional area per unit volume, of oil for the capture of neutrons. The macroscopic capture cross section, i.e. the effective cross-sectional area per unit volume, of water for the capture of neutrons. A trace which has been corrected for slippage velocity. A well log trace which has been filtered to smooth, or average the trace. The measurement of all the naturally occurring gamma radiation separated by energy windows. The conductivity, measured by a spherically focused log, which represents the resistivity approximately one to two feet into the formation. The resistivity, measured by a spherically focused log, which represents the resistivity approximately one to two feet into the formation. The difference in potential (DC Voltage) between a moveable electrode in the borehole and a distant reference electrode usually at the surface. A trace which has been corrected for the effects of spreading loss. A well log trace which has been artificially created, as opposed to an actual measurement, from associated measurements or information. A temperature measurement. A trace which has been corrected for the effects of the temperature in the borehole. The tension on the wireline cable while logging. The ratio of the Thorium measurement to the Potassium measurement. The measurement of gamma radiation emitted by thorium. A measured or measurable period. A trace which has been corrected for the tool diameter. A trace which has been corrected for the effects of the tool not being centered in the borehole. The measurement of all the naturally occurring gamma radiation. The total pore volume occupied by fluid in a rock. A well log used for the purpose of monitoring a traceable material; e.g. a radioactive isotope. The time it takes for an acoustic or electromagnetic wave to traverse a specific distance. The conductivity of fluid-filled rock where fluid distributions and saturations are representative of those in the uninvaded, undisturbed part of the formation. The resistivity of fluid-filled rock where fluid distributions and saturations are representative of those in the uninvaded, undisturbed part of the formation. The distance along a straight, vertical path. Usually computed from a measured depth and deviation information. Porosity calculated from a tube wave acoustic log using a dolomite matrix. Porosity calculated from a tube wave acoustic log using a limestone matrix. The time it takes for a acoustic tube wave to traverse a fixed distance of a given material or matrix. In this case the material or matrix is a specific, zero porosity rock, e.g. sandstone, limestone or dolomite. Porosity calculated from a tube wave acoustic log using a sandstone matrix. The time it takes for a tube acoustic wave to traverse a fixed distance. The measurement of gamma radiation emitted by uranium. directional speed cubic capacity A trace which has been corrected for the effects of the components in a water based borehole fluid system; e.g., a correction for KCL in the mud. A trace which has been corrected for water holdup. The conductivity of rock completely saturated with connate water. The resistivity of rock completely saturated with connate water. The fraction or percentage of pore volume of rock occupied by water. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the type of a message. An alarm condition when something has exceeded specified limits Information about a specific event General information message A cautionary message The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. "Text value" indicates that a text value is expected. "Pressure value" indicates that an equivalentMudWeight value is expected. "Pressure gradient value" indicates that an equivalentMudWeight value is commonly expected but a pressureGradient value may also be specified. "Concentration value" indicates that a concentration value is expected. "Force value" indicates that a force value is expected. "Only" indicates that no other value is expected. Summarizes basic drilling parameters (or changes) at specified depth. Text value only. Text gives bitname and manufacturer. May have other bit parameters typical for bit run. Depth recorded at depth bit run starts. Text value only. Text may include casing depth, size and LOT information. Depth recorded is usually depth of shoe. A top depth is typically not required as it is usually the rig floor, mud line or other datum. However a top depth may be required if referenced to a casing or liner hanger etc Text value only. Any general comments pertinent to chromatograph readings and equipment calibrations, gas reading anomalies, etc. Text value only. Text indicating flowchecks, result, kick details, fluid loss. Any event associated with mud circulation. Text value only. Associated text with core interval usually summarizing core number core, cut, core recovered and percent recovery. Not meant for core description. Text value only. Gas from blendorized cutting samples (possibly every 30ft). Concentration value only. LOT (Leak off) and PIT (Pressure Integrity Test) Results. Pressure value only. Wireline Formation Testing (WFT) pressure (e.g., MDT, RCI, FMT, RFT) as a gradient. Pressure gradient value only. Text comments highlighting anomalies in data or interpretation of drill data: Hookload/WOB, RPM/Torque, PumpFlow. Text value only. Fracture Pressure Gradient - Most Likely. Pressure gradient value only. Text giving gas peak type and magnitude. Text value only. Comments on gas ratio curve data. Text value only. Text describes general engineering/drilling related events Text value only. Pressure gradients derived from kicks and flows while drilling. Pressure gradient value only. Lithlog general comments - would typically appear in 'Remarks' column along with lithologic descriptions. Text value only. Pressures gradients derived from lost returns. Pressure gradient value only. Data on Logging While Drilling tool failures, anomalies etc. Text value only. Indicates a formation or biostratigraphic marker etc. - may include name, measured and subsea depth plus two way time. Text value only. Comment signifying depth at 00:00 hrs. Date is usual text. Text value only. Mud check parameters and changes. Data will be key mud information, MWt, PV/YP, Gels, Viscosity etc. May be just one parameter if change made etc. Text value only. Gives text comments on mud weight etc. As opposed to mud check (see previously). Text value only. General mudlog comments that are normally found in Remarks column with Lith descriptions. May include time / date / depth mudlogging was commenced or other information. Text value only. Overburden Gradient. Pressure gradient value only. Amount of hookload overpull on connection (maximum); Text giving amount of overpull (max) on connections, trips and other. Text should state type of overpull. Both text and force value. Amount of hookload overpull on Trip (maximum per stand); Text giving amount of overpull (max) on connections, trips and other. Text should state type of overpull. Both text and force value. Pore Pressure Gradient - Most Likely. Pressure gradient value only. Estimates of pore pressure made while drilling. Pressure value only. Text comments highlighting anomalies in data or interpretation. Text value only. Text comment highlighting shale density anomalies. Text value only. Text associated with short trip (Wiper Trip) giving details of type and length of trip. Depth is MD at which short trip is made. Text value only. Gives indication of presence of show report (refers to a separate document). Text value only. Associated text for a sidewall core at a specific depth or a comment associated with a sidewall core program / interval. Text may give SWC number, status, lithology etc. Text value only. Interval over which drill bit slides - drilling with no surface rotation. Usually seen as a symbol with generally no associated text. Text listing steam still result - chromatographic breakdown of sample from steam still. Text value only. Comment in regards to drilling survey; may include summary of survey data such as direction, dip and azimuth of survey and measured and TVD depths. Text value only. Text giving comments on temperature data and curves. Text value only. Text comments highlighting anomalies in temperature trend data or interpretation. Text value only. List of wireline logging tools run in this job, usually in run order. Will also include run numbers. Text value only. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. Defines the locations where an equipment tag might be found.. The list of standard values is contained in the WITSML enumValues.xml file. Defines the specifications for creating equipment tags.. The list of standard values is contained in the WITSML enumValues.xml file. Defines the mechanisms for attaching an equipment tag to an item.. The list of standard values is contained in the WITSML enumValues.xml file. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The reason an Optical Time Domain Reflectometry (OTDR) test was run within a Distributed Temperature Survey (DTS). The OTDR was run prior to installing the fiber in the well. The OTDR was run after installating the fiber in the well in order to quality check the installation process. The OTDR was run in conjunction with a DTS run. This is generally immediately preceding the timed run. The OTDR was run for another reason. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. That pit in the active pit system located immediately downstream of the shale shakers, whose primary purpose is to allow the settling and disposal of the larger drilled cuttings not removed by the shale shakers. It is occasionally also called a settling tank. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the type of coordinate system projection method. The source (except for "UserDefined") of the values is Geoshare V13. For a detailed description of each value, see the Geoshare documentation of the indicated "217" object at http://w3.posc.org/GeoshareSIG/technical/GDM/v13.0/. 217-PARAMETERS-PROJECTION-ALBERS 217-PARAMETERS-PROJECTION-AZIMUTHAL 217-PARAMETERS-PROJECTION-CASSINI 217-PARAMETERS-PROJECTION-EQUIDISTANT 217-PARAMETERS-PROJECTION-EQUIRECTANGULAR 217-PARAMETERS-PROJECTION-GNOMONIC 217-PARAMETERS-PROJECTION-LAMBERT-AZIMUTH 217-PARAMETERS-PROJECTION-LAMBERT 217-PARAMETERS-PROJECTION-MERCATOR 217-PARAMETERS-PROJECTION-MILLER 217-PARAMETERS-PROJECTION-OBLIQUE-MERCATOR 217-PARAMETERS-PROJECTION-ORTHO 217-PARAMETERS-PROJECTION-PERSPECTIVE 217-PARAMETERS-PROJECTION-POLAR-STEREO 217-PARAMETERS-PROJECTION-POLYCONIC 217-PARAMETERS-PROJECTION-SINUSOIDAL 217-PARAMETERS-PROJECTION-STATE-PLANE 217-PARAMETERS-PROJECTION-STEREO 217-PARAMETERS-PROJECTION-TM 217-PARAMETERS-PROJECTION-UTM 217-PARAMETERS-PROJECTION-VANDERGRINTEN The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the type of a pump. Centrifugal mud pump Duplex mud mump, 2 cylinders Triplex mud pump, three cylinders The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The type of qualifier of a lithology. The list of standard values is contained in the WITSML enumValues.xml file. These values represent the name of a recording channel. The list of standard values is contained in the WITSML enumValues.xml file. These values represent the type of drilling rig. Barge rig Coiled tubing rig Floating rig Jackup rig Land rig Fixed platform Semisubmersible rig The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. Personnel affected by a risk. measurement while drilling or logging while drilling Type of slow circulation rate. health, safety and environmental The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. Risk Sub-Categories. Rate of Penetration High mud weight (i.e., greater than 10 parts per US gallon). Greater than 2 hours. Greater than 0.5 parts per US gallon. Greater than ten barrles. Greater than 30 minutes. Greater than 2 hours. Greater than 1000 feet per day. Greater than 2000 feet per day. Less than 20 feet per day. Greater than 24 hours. Bottom Hole Assembly Bottom Hole Assembly Bottom Hole Assembly health, safety and environmental Types of risk. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. Type of slow circulation rate. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the type of scope of the drilling target. Generic 3 dimensional target. Defined by the target. Elliptical targets. Includes circle (semi-major = semi-minor axis). Any sections present are ignored. Boundary Conditions. Use sections to describe, length and width ignore. Includes half circle and polygon. Use sections to describe, length and width ignored. Boundary Conditions. Use sections to describe, length and width ignore. Line target Plane target. Used for horizontal wells. Any sections present are ignored. Point Target. Any sections present are ignored. Rectangular Targets. Includes square (length = width). Any sections present are ignored. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the type of scope of a section that describes a target. continuous curve straight line The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the type of a directional survey station. Section terminates at a given azimuth on a given plane target, requires target id Section follows a given buildrate to a specified delta measured depth Section follows a given buildrate to a specified inclination Section follows a given buildrate to a specified measured depth Section follows a given buildrate and turnrate to a specified azimuth Section follows a given buildrate and turnrate to a specified delta measured depth Section follows a given buildrate and turnrate to a specified inclination Section follows a given buildrate and turnrate to a specified inclination and azimuth Section follows a given buildrate and turnrate to a specified measured depth Section follows a given buildrate and turnrate to a specified TVD Section follows a given buildrate to a specified TVD Measured depth casing point, can be inserted within actual survey stations also TVD casing point, can be inserted within actual survey stations also Section follows a given dogleg severity Section follows a given dogleg severity to a specified measured depth and azimuth Section follows a given dogleg severity until a specified TVD and Azimuth Section follows a given dogleg severity until a specified Inclination Section follows a given dogleg severity to a inclination and azimuth Section follows a given dogleg severity to a specified measured depth and inclination Section follows a given dogleg severity until a specified TVD and Inclination Section follows a given dogleg severity to a specified target TVD, NS, EW Section follows a given toolface angle and dogleg severity to a specified azimuth Section follows a given toolface angle and dogleg severity to a specified delta measured depth Section follows a given toolface angle and dogleg severity to a specified inclination Section follows a given toolface angle and dogleg severity to a specified inclination and azimuth Section follows a given toolface angle and dogleg severity to a specified measured depth Section follows a given toolface angle and DLS to a specified TVD Measured depth formation, can be inserted within actual survey stations also TVD formation, can be inserted within actual survey stations also Inertial Gyro MWD Gyro measurement North seeking gyro Section holds angle, azimuth to a specified delta measured depth Section holds angle, azimuth to a specified measured depth Section holds angle, azimuth to a specified TVD Section follows a continuous curve to a specified inclination, azimuth and measured depth Magnetic Multi shot Measurements while Drilling tool, magnetic Magnetic Single shot Measured depth marker, can be inserted within actual survey stations also TVD marker, can be inserted within actual survey stations also Specified as TVD, NS, EW, could be used for point or drilling target (non geological target) Specified as TVD, NS, EW of target center, requires target id association Specified as TVD, NS, EW of target offset, requires target id association Tie in point for the survey Section follows a given turn rate to a azimuth Section follows a given turn rate to a given delta measured depth Section follows a given turn rate to a given measured depth Section follows a given turn rate to a given TVD The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. Drill colllar made from non-magnetic material. Used to avoid magnetic interference with downhole directional measurements. Drill string component with blades that help keep the drill string away from the sides of the hole. A sub that is used with a downhole motor to change the direction of the wellbore. It can be adjusted to give a variable angle of deviation. A downhole tool used in conjunction with a jar that stores energy for rapid release when the jar is fired. Depending on the operating mode, the energy in tension or compression is stored by means of a mechanical spring or compressible fluid such as nitrogen gas. A downhole tool that can steer the progress of the bit by applying forces to the sides of the hole while drilling with rotating pipe. A drill string component that has a fixed bend angle. Used in conjunction with a downhole motor for deviating the wellbore. A diamond tipped drill bit used for coring Polycrystalline diamond compact core bit. Drill bit with cutters containing diamonds. Roller cone bit with cutters made from tungsten carbide or other wear resistant material. Roller cone drill bit with steel teeth. Polycrystalline diamond compact drill bit. Drill string component used to connect the drill bit to the rest of the string. A downhole tool that is located and set to isolate the lower part of the wellbore. A blank end component substituting for a bit, when re entering an already existing hole to guide the BHA, to avoid inadvertent sidetracks, such as when run below a hole opener in an existing hole. A solid plug used as an isolation device in piping systems, conduits or wellbore tubulars. A spring loaded component used to minimize variations in weight transfer to the drill bit. Tubing used to line the wellbore and protect against pressure differences between the wellbore fluids and the formation. Tool used for cutting through casing. Component used to hang a casing string from the well head at the sea bed. Component used to hang casing from a surface location on land or a fixed platform. The adapter between the first casing string and either the BOP stack (during drilling) or the wellhead (after completion). Component used to allow venting part of the drilling fluids into the annulus rather than through the bit. Section of coiled tubing that is inside the wellbore. Section of coiled tubing that is on the coil. Strengthened drill pipe. Tool used with a coring bit to retrieve geological core samples. Core barrel used to sample geological cores at a know orientation. Sub used to convert from one thread type or size to another. Component used to convert between casing threads and/or sizes. A sub that controls activation of tools by means of dropping a dart down the drillstring. Die collar with left-handed thread. A tool that permits control of the drilling direction. Heavy pipe without tool joints used to apply weight to the bit. Pipe used to convey the drilling assembly to the bottom of the hole. Left-handed thread drill pipe Bottom Hole Assembly for drill stem testing Pipe that is driven into the ground or sea bed to start drilling a well. A type of overshot tool used in fishing stuck pipe. A type of overshot tool used in fishing stuck pipe. A short length of casing fitted with a check valve. Prevents fluids from flowing back up the tubular string. A tapered, often bullet-nosed device fitted with a check valve and typically found at the bottom of a casing string. A valve, plunger or flapper, run in a drill collar to prevent fluid flow and debris into the string while running in hole. Sometime ported with a small leak path to allow shut in drillpipe pressure readings. A tapered, often bullet-nosed piece of equipment often found on the bottom of a casing string. Helps to guide the casing down the center of the hole when a casing string is being run into the hole. Component used for hanging the Measurement While Drilling tool. A type of drillpipe whose walls are thicker and collars are longer than conventional drillpipe. Left-handed thread heavy weight drill pipe. Marine riser used for deep water or high pressure applications Drill bit used for enlarging the hole. Expandable device used for packing off or isolating a section of wellbore used for performing well pressure tests. Downhole mud motor that can also take measurements of downhole drilling parameters. Hydraulic or spring-loaded component used to free stuck pipe. Component used to collect debris from the bottom of the hole. Component used to collect debris from the bottom of the hole when reverse circulating Component used to collect debris from the bottom of the hole. Hexagonal or square pipe used to rotate the drill string from the rig floor. Tool used to open out narrow sections of open hole caused by pipe friction in tight radius bends. A component installed near the bottom of the casing string on which the cement plugs land during the primary cementing operation. Tool run on pipe or wireline to engage the top of a fish, and enable the condition of the exposed end of the fish to be ascertained from the pattern in soft lead in the tool. Casing or tubing that is hung from the inside of existing casing rather than from the sea bed or surface. Component that is used to hang liner from inside casing. Magnet used to retrieve magnetic debris from the hole. Large diameter pipe that connects from the sea bed to an offshore rig. Milling tool used to dress or clean up pipe that is to be retrieved from the hole. Flat bottomed milling tool, used to tidy up the broken end of pipe stuck in the hole prior to fishing. Hollow milling tool Tapered milling tool. Large diameter milling tool that goes over the end of stuck pipe. Tool used to hang casing in multi-lateral wellbores. Downhole tool, usually powered by fluid flow, that rotates the drill bit. Tool that can take downhole measurements of formation properties and wellbore direction while drilling. Stabilizer that is placed close to the bit Stabilizer placed near the bit to provide directional control. Stabilizer that does not rotate with the drill string. Sub used to orient the drill string for directionla drilling. Tool used for retrieving pipe that has been lost in the hole. Left-handed overshot tool. Specific type of overshot tool used for fishing. Component that can be inflated so that it seals off a section of the wellbore, typically for formation testing. Milling tool used in fishing stuck pipe. Tool for cutting through pipe that has become stuck in the hole. Component with a port or vent tha allows mud to be circulated into the annulus. A type of screen used in sand control applications to support the gravel pack. Component used to relieve wellbore pressures. Riser pipe used to carry produced fluids. Measurement While Drilling component that send encodes downhole data into hydraulic pulses that can be detected and decoded at the surface. Component that provides a restriction to mud flow to control hydraulics. Torque Transmission A downhole tool that is designed to enable communication between the tubing internal diameter and the annulus, typically for reverse-circulation purposes A stabilizer that has rotating rollers rather than fixed blades to reduce friction with the sides of the hole. Retrievable packer, designed for testing, treating, and squeezing. A weak spot in the drillstring so that if tension in the drillstring exceeds a predetermined amount, the safety joint will part and the rest of the drillstring will be salvageable. Left-handed threaded safety joint providing a weak spot in the drillstring so that if tension in the drillstring exceeds a predetermined amount, the safety joint will part and the rest of the drillstring will be salvageable. Component used to reduce wear on the threads of components such as drill bits that are often re-used. A device for cleaning mud and mud filter cake off of the wellbore wall when cementing casing in the hole to ensure good contact and bonding between the cement and the wellbore wall. Screw-in casing shoe. Short drill collar used to adjust the length and spacing of BHA components. Liner casing that has slots to allow passage of produced fluids. Fishing tool that attaches to the inside of the stuck pipe by threads or grapples. Downhole motor, usually powered by mud flow, that can be steered. Retrievable packer, designed for testing, treating, and squeezing. Pipework that connects the top of the drillstring to the mud pumps. Tool used to tap a thread into components that are stuck in the hole. Left-handed thread tapping tool. Perforating gun that is deployed on the end of a tubular string rather than a wireline Drilling tool used to maintain weight on bit. Tool used to position a tie-back string of tubing connecting a liner to the surface. Small diameter pipe that is run inside casing or tubing as part of the well completion. Component used to hang tubing inside casing or liner. Downhole device used for directional drilling, powered by mud circulation that rotates the drill bit while the drill string remains non-rotating Component that is run behind the bit and opens out the hole to a larger diameter. Stabilizer with blades that can be adjusted to varying diameters. Large diameter pipe with an internal grapple used for retrieving stuch pipe. Milling tool shaped like a watermelon. Wedge shaped tool used to drill off in a different direction. Anchor device used to position whipstock. Stabilizer with adjustable blades to allow steering the drilling direction. Milling tool used for cutting through casing. Tool used to enlarge the hole. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. Type of direcional survey tool; very generic classification The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The direction of flow of the fluids in a well facility (generally, injected or produced, or some combination). The well facility alternately injects (usually a steam or hot fluid) and produces. The well facility is injecting fluids into the subsurface. The well facility is producing fluids from the subsurface. The flow direction of the fluids is variable, but not on a regular basis as is the case with the huff-n-puff flow. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The type of fluid being produced from or injected into a well facility. This is generally an injected fluid. Liquid hydrocarbons produced with natural gas that are separated from the gas by cooling and various other means. Condensate generally has an API gravity of 50 degrees to 120 degrees and is water white, straw, or bluish in color. It is the liquid recovery from a well classified as a gas well. It is generally dissolved in the gaseous state under reservoir conditions but separates as a liquid either in passing up the hole or at the surface. These hydrocarbons, from associated and nonassociated gas well gas, normally are recovered from lease separators or field facilities by mechanical separation. The well facility is classified as a dry well. It has not been, nor will it be used to produce or inject any fluids. The well is classified as a gas well, producing or injecting a hydrocarbon gas. The gas is generally methane, but may have a mixture of other gases also. The well facility is classified as producing both gas and water. This classification is to be used when the produced stream flow is a mixture of gas and water. When a facility produces gas and water in separate streams, it should be classified twice as gas and as water. The well produces or injects non hydrocarbon gases. Typical other gases would be helium and carbon dioxide. Carbon Dioxide gas. The liquid hydrocarbon, generally referred to as crude oil. The well facility is classified as producing both gas and oil. This classification is to be used when the produced stream flow is a mixture of oil and gas. When a facility produces oil and gas in separate streams, it should be classified twice as oil and as gas. The well facility is classified as producing both oil and water. This classification is to be used when the produced stream flow is a mixture of oil and water. When a facility produces oil and water in separate streams, it should be classified twice as oil and as water. The gaseous state of water. This is generally an injected fluid, but it is possible that some hydrothermal wells produce steam. The well is classified as a water well without distinguishing between brine or fresh water. The well facility is classified as producing or injecting salt water. The well facility is classified as producing fresh water that is capable of use for drinking or crop irrigation. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the classification of a wellbore based on its shape. The source of the values and the descriptions is the POSC V2.2 "facility class" standard instance values in classification system "POSC wellbore trajectory shape". A wellbore configuration where the inclination is increased to some terminal angle of inclination and maintained at that angle to the specified target. A wellbore that significantly departs from vertical with respect to the surface location. Incorporates two tangential (constant, non-zero inclination) sections. The second of which must be at a higher inclination than the first. A wellbore whose path deviates from the vertical by at least 75 degrees. A wellbore drilled with a vertical segment, a deviated segment, and a return toward a vertical segment. A wellbore that is nearly vertical with respect to the surface location. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. The classification of a wellbore with respect to its parent well/wellbore. The original wellbore had to be abandoned before its final usage. This wellbore is being drilled as a different wellbore, but one which has the same target as the one that was abandoned. This is the first wellbore that has been drilled, or attempted, in a given well. The wellbore is being redrilled. The wellbore is being reentered after a period of abandonment. The wellbore is part of an existing regulatory well. The original borehole did not reach the target depth. This borehole required the well to be respudded (drilled from a different surface position). The wellbore is a deviation from a given wellbore, that produces a different borehole from the others, and whose bottomhole differs from any previously extisting wellbore bottomholes. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the classification of a well or wellbore by the purpose for which it was initially drilled. A well drilled into a formation shown to be potentially productive of oil or gas by an earlier well for the purpose of obtaining more information about the reservoir. Also known as a delineation well. An appraisal well, generally drilled in a location interpreted to be in the reservoir, whose purpose is to confirm the interpretation. An appraisal well, generally drilled in an area unknown to be part of the reservoir, whose purpose is to determine the extent of the reservoir. An exploratory well drilled in an unproved area to test for a new field, a new pay, a deeper reservoir, or a shallower reservoir. Also known as a wildcat. An exploratory well drilled to search for additional pools of hydrocarbon in close proximity to known pools of hydrocarbon but at a deeper stratigraphic levels than the known pools. An exploratory well drilled to search for an occurrence of hydrocarbon at a relatively considerable distance outside the limits of known pools of hydrocarbon, as those limits were understood at the time. An exploratory well drilled to search for additional pools of hydrocarbon in close proximity and at the same stratigraphic level as known pools. An exploratory well drilled to search for additional pools of hydrocarbon or to extend the limits of a known pool by searching in the same interval at some distance from a known pool. An exploratory well drilled to search for additional pools of hydrocarbon in close proximity, but at a shallower stratigraphic levels than the known pools. A well drilled in a zone in an area already proved productive. A development well drilled to fill in between established wells, usually part of a drilling program to reduce the spacing between wells to increase production. A development well drilled with the intent of injecting fluids into the reservoir for the purpose of improving reservoir production. A development well drilled with the intent of producing fluids. A well drilled for storing fluids - generally either hydrocarbons or waste disposal. A well drilled with the intent of injecting gas into the reservoir rock as a storage facility. A well drilled with the intent of providing a general service as opposed to producing or injecting fluids. Examples of such services are geologic tests, pressure relief (for blowouts), and monitoring and observation. A service well drilled to intersect another well below the surface for the purpose of extending the life of a well whose surface borehole has been lost or damaged. A service well drilled for the purpose of monitoring fluids in a reservoir, or observing some other subsurface phenomena. Also called a monitor well. A service well drilled with the specific purpose to provide communication at some point below the surface to another well which is out of control. A well drilled with the purpose of obtaining information on the stratigraphy, on drilling practices, for logging tests, or other such purpose. It is not expected to find economic reserves of hydrocarbons. A research well drilled to test the suitablity of a particular type of equipment or drilling practice. A research well drilled for the purpose of gathering geologic information on the stratigraphy of an area. A C.O.S.T. well would be included in this category. A service well drilled for the purpose of injection of sewage, industrial waste, or other waste fluids into the subsurface for disposal. A non-oil and gas E and P well drilled for the purpose of locating and/or extracting a mineral from the subsurface, usually through the injection and/or extraction of mineral-bearing fluids. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations. These values represent the status of a well or wellbore. The status of a facility in which drilling, completion, and production operations have been permanently terminated. For a well to be active, at least one of its wellbores must be active. For a wellbore to be active, at least one of its completions must be actively producing or injecting fluids. Fluids are actively being injected into the facility. Fluids are actively being produced from the facility. The completion has been installed, but the facility is not yet active. This status is appropriate only before the initial producing or injecting activity. The status of a well or wellbore in which drilling operations have begun, but are not yet completed. The status ends when another status becomes appropriate. The wellbore has been plugged from the bottom, but only partially to the point where it intersects another wellbore. The facility has received regulatory approvel, but drilling has not yet commenced. For a well, it has been spudded. For a subsequent wellbore, the whipstock or similar device has not yet been set. An abandoned well (or wellbore) whose wellbores have been plugged in such a manner as to prevent the migration of oil, gas, salt water, or other substance from one stratum to another. Generally the criteria for this status is controlled by regulatory authorities. The status of a well or wellbore from conception to either regulatory approval or commencement of drilling. The facility has been sold, so it is no longer appropriate to keep a close internal status value. Status values may be added at later times without changing the sold status. Production or injection has been temporarily suspended in a manner that will allow immediate resumption of activities. Production or injection has been temporarily suspended in a manner that will not allow immediate resumption of activities. The facility operations are suspended while tests are being conducted to determine formation and/or reservoir properties. For example, a drillstem test. This status also includes extended testing. Information about the status of the well is confidential. This is more explicit than unknown, since it gives the reason that the status value is unknown. Maintenance or data acquisition on a well during the production phase. This includes any relevant job which can be done while the well is shut in. This includes many jobs that occur when a well is re-entered. The value is not known. This value should not be used in normal situations. All reasonable attempts should be made to determine the appropriate value. Use of this value may result in rejection in some situations.