TRYM-DPR2.0-28-FEB-2012-dpr2-welltests.xml
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<?xml version="1.0" encoding="UTF-8"?>
<objects xmlns:xsi="http://www.w3.org/2001/XMLSchema-instance"
xmlns="http://www.epim.no/schemas/mprml/1" version="1.0(MPRML)">
<documentInfo>
<DocumentName namingSystem="EC">TRYM February 2012</DocumentName>
<DocumentAlias namingSystem="EC">TRYM Copex Report</DocumentAlias>
<DocumentDate>2012-03-04T00:00:00.0Z</DocumentDate>
<documentClass namingSystem="EC">Dong E&P Norge AS</documentClass>
<documentClass namingSystem="EC">DPR 2.0</documentClass>
<documentClass namingSystem="ERH">dpr2</documentClass>
<FileCreationInformation>
<FileCreationDate>2012-03-14T00:00:00.0Z</FileCreationDate>
<SoftwareName>Energy Components</SoftwareName>
<FileCreator>Dong E&P Norge AS</FileCreator>
<Comment>NA</Comment>
</FileCreationInformation>
<Owner>Dong E&P Norge AS</Owner>
</documentInfo>
<context xsi:type="obj_report">
<kind>DPR 2.0</kind>
<title>TRYM</title>
<date>2012-02-28</date>
<dateEnd>2012-02-28</dateEnd>
<month>2012-02</month>
<year>2012</year>
<reportVersion>1.2</reportVersion>
<reportStatus>final</reportStatus>
<installation kind="field" namingSystem="NPD" uidRef="18081500">TRYM</installation>
<operator>
<name>Dong E&P Norge AS</name>
<role>Operating company</role>
</operator>
</context>
<object xsi:type="obj_wellTest">
<nameWell>3/7-A-1</nameWell>
<name>Injection well test for well 3/7-A-1</name>
<wellContext>
<field namingSystem="NPD">TRYM</field>
</wellContext>
<testDate>2012-02-28T00:00:00.0Z</testDate>
<previousTestDate>2012-02-15T00:00:00.0Z</previousTestDate>
<lastValidTest>2012-02-20T00:00:00.0Z</lastValidTest>
<testReason>revision</testReason>
<testType>pressure buildup</testType>
<standardTempPres>0 degC 1 atm</standardTempPres>
<fluidLevelTest>
<fluidLevel uom="m">87.28</fluidLevel>
<baseUsableWater uom="m">148.38</baseUsableWater>
<testedBy>For any transformati</testedBy>
</fluidLevelTest>
</object>
<object xsi:type="obj_wellTest">
<nameWell>3/7-A-1</nameWell>
<name>Injection well test for well 3/7-A-1</name>
<wellContext>
<field namingSystem="NPD">TRYM</field>
</wellContext>
<testDate>2012-02-28T00:00:00.0Z</testDate>
<previousTestDate>2012-02-13T00:00:00.0Z</previousTestDate>
<lastValidTest>2012-02-23T00:00:00.0Z</lastValidTest>
<testReason>periodic</testReason>
<testType>pressure buildup</testType>
<injectionTest>
<testDuration uom="h">12</testDuration>
<testInterval>
<mdTop uom="m">2539.09</mdTop>
<mdBase uom="m">2559.62</mdBase>
<wellbore>3/7-A-1 AH</wellbore>
<testedFormation>Brent</testedFormation>
<valvePosition uom="ft/m">2741.07</valvePosition>
</testInterval>
<InjectedFluid>gas</InjectedFluid>
<wellTestCumulative>
<cumulativeOil uom="m3">3656.29</cumulativeOil>
<cumulativeGas uom="m3">46292.03</cumulativeGas>
<cumulativeWater uom="m3">1815.54</cumulativeWater>
</wellTestCumulative>
<chokeOrificeSize uom="in/64">85.99</chokeOrificeSize>
<minimumAnnularPressure uom="bar">173.78</minimumAnnularPressure>
<maximumAnnularPressure uom="bar">215.83</maximumAnnularPressure>
<wellheadFlowingPressure uom="bar">61.28</wellheadFlowingPressure>
<wellheadMaximumPressure uom="bar">116.67</wellheadMaximumPressure>
<injectionTestResults>
<oilVolume>
<volumeStdTempPres uom="m3">3625.65</volumeStdTempPres>
<densityStdTempPres uom="kg/m3">775.08</densityStdTempPres>
</oilVolume>
<oilRate>
<fluidRateStdTempPres uom="m3/h">636.97</fluidRateStdTempPres>
</oilRate>
<gasVolume>
<volumeStdTempPres uom="m3">6656.92</volumeStdTempPres>
<densityStdTempPres uom="kg/m3">1.39</densityStdTempPres>
</gasVolume>
<gasRate>
<fluidRateStdTempPres uom="m3/h">3631.1</fluidRateStdTempPres>
</gasRate>
<waterVolume>
<volumeStdTempPres uom="m3">112.13</volumeStdTempPres>
</waterVolume>
<waterRate>
<fluidRateStdTempPres uom="m3/h">132.85</fluidRateStdTempPres>
</waterRate>
</injectionTestResults>
</injectionTest>
</object>
<object xsi:type="obj_wellTest">
<nameWell>3/7-A-1</nameWell>
<name>Production well test for well 3/7-A-1</name>
<wellContext>
<field namingSystem="NPD">TRYM</field>
</wellContext>
<testDate>2012-02-28T00:00:00.0Z</testDate>
<previousTestDate>2012-02-17T00:00:00.0Z</previousTestDate>
<lastValidTest>2012-02-20T00:00:00.0Z</lastValidTest>
<testReason>initial</testReason>
<testType>pressure buildup</testType>
<productionTest>
<testDuration uom="h">4</testDuration>
<bottomholeData>
<bottomholePres uom="bar">104.11</bottomholePres>
<bottomholeTemp uom="degC">106.44</bottomholeTemp>
</bottomholeData>
<separatorData>
<separatorPressure uom="bar">76.78</separatorPressure>
<separatorTemperature uom="degC">50.43</separatorTemperature>
</separatorData>
<operatingMethod>pumping</operatingMethod>
<productionTestResults>
<oilVolume>
<volumeStdTempPres uom="m3">1944.57</volumeStdTempPres>
<volume uom="m3">2476.18</volume>
<densityStdTempPres uom="kg/m3">746.54</densityStdTempPres>
</oilVolume>
<oilRate>
<fluidRate uom="m3/h">550.68</fluidRate>
<fluidRateStdTempPres uom="m3/h">635.67</fluidRateStdTempPres>
</oilRate>
<gasVolume>
<volumeStdTempPres uom="m3">2284.26</volumeStdTempPres>
<volume uom="m3">2469.2</volume>
<densityStdTempPres uom="kg/m3">1.93</densityStdTempPres>
</gasVolume>
<gasRate>
<fluidRate uom="m3/h">1918.6</fluidRate>
<fluidRateStdTempPres uom="m3/h">2322.67</fluidRateStdTempPres>
</gasRate>
<waterVolume>
<volumeStdTempPres uom="m3">2101.57</volumeStdTempPres>
<volume uom="m3">2361.7</volume>
</waterVolume>
<waterRate>
<fluidRate uom="m3/h">2247.15</fluidRate>
<fluidRateStdTempPres uom="m3/h">2370.79</fluidRateStdTempPres>
</waterRate>
<gasOilRatio uom="%">57.58</gasOilRatio>
<basicSedimentAndWater uom="%">5.27</basicSedimentAndWater>
<oilPotential uom="1000m3/d">174.11</oilPotential>
<gasPotential uom="1000m3/d">104.06</gasPotential>
<sandVolume uom="m3">1.65</sandVolume>
</productionTestResults>
</productionTest>
</object>
</objects>