DTI Petroleum Operations Notice
No. 9 Record and sample requirements for seaward surveys and wells

Any enquiries regarding this Notice should be addressed to :

Notes :

Summary table.

1. This Notice applies to all wells; Exploration, Appraisal, and Development, in both Landward and Seaward areas. Please read the Notice fully before sending any information.

2. Other information required to control operations in offshore areas or wells before, during and at the end of drilling are the subject of the following DTI UKCS Guidance Notes :

• PON 4 Application for Consent to Drill Exploration, Appraisal, and Development Wells
• PON 5 Application to Abandon or Temporarily Abandon a Well
• PON 8 Application to Complete and/or Workover a Well
• PON 12 Department of Trade and Industry Well Numbering System
• PON 14 Application for Consent for Geophysical Surveys

3. A summary of requirements, the destination for records and samples, and the timeframe within which the items should be sent, is attached at the back of this Notice. Addresses can be found in section 10.

4. Data format standards The DTI are committed to the emerging POSC (Petroleum Open Software Corporation) international standards. There is an intention, over a period of time, to redefine many of the required data items as POSC digital exchange files. The DTI will work closely with the UK CDA (Common Data Access) initiative, to develop the digital exchange standards.

5. Geophysical records

2.1 Proposed geophysical surveys

Operators must advise the DTI and any other parties specified in the licence conditions, of proposed Geophysical Surveys 28 days before the Survey is commenced. The Proforma in PON 14 MUST be used. In an area which is known to have coal potential, in addition to normal planning requirements, the Operator should also consult the Coal Authority before commencing a seismic programme.

2.2 Seismic data (including 'speculative' and 'group' shoots)

1. A UKOOA format magnetic tape of the location data, ideally within 3 months of data acquisition. When many surveys are being performed their location data can be compiled onto a tape(s) and sent biannually at the beginning of and mid year.

The boundary points (Latitude and Longitude) of each survey should be indicated on the tape label, or on the transmittal.

Only if requested, the following data should be supplied within 30 days of the request .

2. One reproducible transparency of each seismic section, both filtered and migrated where available, at a vertical scale of 10cms/second.

3. Digital field data, one reproducible transparency per velocity analysis, relative amplitude and reprocessed sections.

4. Digital data on exabyte tape in SEGY format suitable for loading on a geophysical workstation.

2.3 Site survey data (if requested)

1. One reproducible transparency of each final processed seismic section together with a reproducible transparency of the shot point location map at suitable scale.

2. Where acquired, copies of side scan sonar records with their track charts.

3. If available, a copy of the final interpretation report of the sea bed/superficial deposits investigation of drilling locations or installation sites.

These data comprise the detailed record of the survey and are not the results asked for by PON 4 section 7 concerning shallow gas.

2.4 Magnetic data (if requested)

Supplied on magnetic tape, the following information should be included:

1. Proprietorship of the data

2. Seismic or aircraft contractor, acquisition contracor, processing contractor

3. Survey type (marine, land, airborne), navigation system type

4. Survey dates

5. Map projection, spheroid, datum, central meridian

6. Navigation position

7. Magnetometer type

8. Base magnetometer (diurnal monitor) type, location

Line (point) data:

1. Line name / number

2. Observation point or fiducial number

3. Latitude and Longitude

4. X and Y (in metres)

5. Julian Day

6. Time in GMT (seconds to 2 decimal places for high resolution data)

7. Water depth, elevation or flight height (metres, 1 or 2 decimal places for high resolution or land data)

8. Raw magnetic reading (nT) (state if offset corrected)

9. Base magnetometer reading (if available) (nT)

10. International Geomagnetic Reference Field (IGRF) (nT)

11. Filtered magnetic reading minus IGRF (nT)

12. Base magnetometer corrected filtered magnetic reading minus IGRF (if appropriate) (nT)

13. Adjusted / smoothed Magnetic Anomaly (nT)

A navigation tape in UKOOA format is also required if this information is not on the line data tape.

2.5 Gravity data (if requested)

Supplied on magnetic tape, the following information should be included:

1. Proprietorship of the data

2. Seismic or aircraft contractor, acquisition contractor, processing contractor

3. Survey type (marine, land, airborne), navigation system type

4. Survey dates

5. Map projection, spheroid, datum, central meridian

6. Navigation position, gravity meter offset

7. Gravity meter type, serial number

8. International Gravity Formula used

9. Density used for Bouguer or terrain correction

Line (point) data:

1. Line name / number

2. Observation point or fiducial number

3. Latitude and Longitude

4. X and Y in metres

5. Julian Day

6. Time in GMT (seconds to 2 decimal places for high resolution data)

7. Water depth, elevation or flight height (metres, 1 or 2 decimal places for high resolution or land data)

NB The water depth supplied should be that used in calculation of the Bouguer correction; ie it may not have been tide corrected, filtered, adjusted etc.

8. Raw gravity (mgals) (recalculated from gravity meter raw output if possible; state if offset corrected)

9. Instrument drift if available (mGals)

10. Eotvos correction or terrain correction (mGals)

11. Free Air gravity (mGals)

12. Bouguer gravity (mGals)

13. Adjusted / smoothed Free Air gravity (mGals)

14. Adjusted / smoothed Bouguer gravity (mGals)

A navigation tape in UKOOA format is also required if this information is not supplied on the line data tape.

2.6 Other geophysical survey data

When data is acquired using other geophysical methods (e.g. Resistivity) the DTI may wish to discuss the nature of the data to be supplied with the Licensee.

6. Well records This part of this notice sets out the information required from all wells. Subsections 3.4 and 3.5 describe the additional information required in respect of development wells.

3.1 Data required on a well prior to drilling

Various data should be submitted with the consent to drill application. Requirements are fully listed in DTI PON 4.

3.2 Data to be supplied during drilling operations

1. Notification of spud should be sent to the Well Consents Team at the earliest opportunity, but preferably within two hours of spudding. In the case of Exploration and Appraisal wells, this is when the bit has penetrated the ground or the sea floor. For Development wells (or wells where there is a preset casing) the notification of spud should be sent within two hours of drilling out of preset casing (usually 20") with intent to drill to the reservoir target.

Information to be supplied :

1. Quad and Block number and Target reference (alphabetic), or the well name and target reference in the case of Landward wells;

2. the name of the licence operator and well operator if different;

3. contact name and fax number for return of the DTI well number (see PON 12);

4. the date and time of spud; and

5. actual top hole location

2. Application for consent to suspend a well, where required, should be made as soon as possible after the results of the well are known. A fax of the Proforma in PON 5 with Well Summary information together with a cover requesting consent to temporarily abandon the well should be sent to the Well Consents Team. Where consent is not required under the Regulations appropriate to the licence, a fax of the Proforma should still be submitted with the Well Summary information.

3. Where a well is to be abandoned immediately after drilling, application for consent to abandon should be made as soon as possible after the results of the well are known. A fax of the Well Summary together with a cover requesting consent to abandon the well should be sent to the Well Consents Team.

4. Petrophysical logs should be supplied within 4 weeks of the survey unless specifically requested earlier.

1. As reproducible transparencies at a scale of 1:200

2. In digital industry standard format, i.e. LIS, BIT or API . The logs should be clearly labelled with DTI Well Registration Number, tool type and run depth range. They should be accompanied by a photocopy of the log print header.

5. Licensees are reminded that, if an Exploration well is successful and they wish to publish the results, they should pass text for approval through the DTI Press Office Tel. 020 7215 5983 prior to release, preferably giving 48 hours notice.

3.3 Information required on completion of a well

1. Completion report

Within 6 months of the completion of any well including abandonment, or suspension after reaching the first potential producing horizon, the following information must be included in a completion report (NOT a Mudlogger's Report) :

2. General Data :

1. DTI Well Registration Number (see PON 12 ) and the target reference for the well. [Where the operator has its own numbering system on fields the alternative number should be included. Additionally for development wells not covered by platform or template designation indicate their field name and top hole reference.]

2. Status of well - i.e. abandoned, suspended, production, injection or observation.

3. Well Chronicle - dates of rig on location, drilling commenced (spud), drilling completed, operations completed and rig off location. Intermediate dates and depths should be included where operations were suspended for any reason prior to end of operations on the well.

4. Height of drilling reference point (e.g. KB or RT or RF) above mean sea level and sea bed and water depth.

5. Sea bed location - Latitude and Longitude (UTM Eastings and Northings with Central Meridian used if calculated) with final positioning report. For wells drilled from templates or platforms provide the coordinates (Latitude and Longitude plus UTM E and N) of the centre of the installation and slot number location.

6. Total Depth. If there is significant deviation programmed or otherwise give TVD of total depth, Latitude and Longitude plus UTM E and N with bearing and distance from top hole location.

7. Drilling unit.

8. Licence number and round with licence operator.

Geological and Petroleum Engineering Data:

1. Geological table of formations encountered giving depths (MD and TVDSS) and thickness (apparent and TVTH). A brief geological description, with significant age determinations and structural information (dips and faults, include true stratigraphical thickness if applicable).

2. A listing or log of hydrocarbon indications recorded whilst drilling.

3. A record of all cores and side wall cores, intervals and recoveries together with stratigraphical core log, conventional poroperm results and any special core analyses including those to determine petrophysical rock parameters.

4. A record of all logs taken (see also subsection 3.2 of this note) with brief determinations of porosity and water saturations in reservoirs and potential reservoir. In addition where applicable despatch separately from the completion report as reproducible transparencies and tape copies, all further reprocessed logs such as dipmeters and true vertical depth logs if not previously sent.

5. The depths (MD and TVDSS) and results of all repeat formation tests peformed in the well. State whether psi(a) or psi(g).

6. The depths (MD and TVDSS) and results of all drill stem and/or production tests of the well. This to include details of intervals, chokes, rates and/or volumes of hydrocarbons and/or water obtained and their gravities together with pressure and temperatures measured with computer extrapolated reservoir pressure and reference depth. Additionally the results of the test should include perforation details of type, size, density of shots and when applicable details of stimulation such as type, volume, rate, pressures.

7. The results of chemical and physical analyses of fluids produced by testing or of minerals found in the well.

Drilling Data:

1. Drilling history of the well including mud record, chronological report and as an appendix copies of all drilling reports with the exception of the IADC and other daily reports, clear copies of which should be available on demand to the Department. In addition, transparencies of the drilling logs should be provided.

2. Details of the well's casings/liners and their seat depths including cement volumes, location of cement tops outside the casings and the method of location. Company/contractors cementing reports and records should be submitted as an appendix. Details of all formation integrity tests whether or not immediately below casing seats are required. Information should be supplied as total pressure versus depth indicating either that leak off has been achieved or that it was a simple limit test.

3. The kick-off point of a side-tracked or deviated hole. The deviation data should be submitted on magnetic tape.

4. If the well is abandoned or suspended details of packers, plugs, casing retrieval and site clean up. A diagram showing all components, cement, perforations and obstructions left in the hole are required.

5. If the well is completed details of packers, subsurface chokes; nipples and safety valves; tubing size, grade weight and pipe thread and well head Christmas tree. In the case of sub-sea satellite completions details of flow line connection are required.

6. A completion diagram (where applicable) showing components of the completion, casing strings, cement tops, perforations and obstructions left in the hole is required.

3. Geological Composite Log (1:500 scale) The DTI Well Registration Number, with Land Well Name if appropriate, should be prominent on the header. For Development wells, the slot number should also be indicated (see PON 12). The Operators well number, if different, may be added. The Composite Log should integrate the geological columnar section with selected petrophysical logs i.e. a lithology indicating log, a porosity log and a resistivity log. The log should indicate all coring intervals, testing intervals and casing/liner seats and it should carry abbreviated information concerning the geology and testing.

NB TWO copies of the Geological Composite log should be supplied on paper, & ONE copy as a reproducible transparency, WITHIN SIX MONTHS OF THE END OF WELL OPERATIONS

4. Well velocity information The results of any velocity surveys and vertical seismic profiling including reproducible transparencies of velocity logs, VSPs and synthetic seismograms, within three months.

3.4 Required post completion of wells

Within 2 months of availability, the following records are required in respect of development wells.

1. Results of any significant chemical and physical analysis of petroleum including PVT analyses, water or minerals found in the well or injected into the formation subsequent to well completion report (see subsection 3.3).

2. Results of any significant physical analysis carried out on rock samples or fluid from the well including special analyses to determine matrix or fluid parameters subsequent to well completion report.

3. Results of any significant tests on production, injection and observation wells including downhole formation pressure and temperature surveys carried out, and also including time, pressure and flow listings of draw down and build-up surveys subsequent to well completion report.

4. Any measurements relating well-head to down-hole pressures (static or flowing) should be reported.

5. Details of any changes in perforations or completion hardware or any further operations to stimulate or inject fluids. The TVD or drilled depth of flowing perforation intervals should be reported.

6. Details of any other significant changes to the well (see PON 8).

3.5 Additional information required on completion of development wells

Within 6 months, unless requested earlier, of the completion of a development well the following information concerning the reservoir should be included in the completion report additional to that required in subsection 3.3. Much of these data should be presented in tabular or diagrammatic form.

1. Reservoir unit tops as depths (MD and TVDSS) and thickness (apparent and TVTH).

2. Fluid contacts or limits i.e. gas/oil, or oil/water, or gas/water or lowest known occurrences of hydrocarbon fluids as depths (MD and TVDSS).

3. Sub sea geographical (plan) co-ordinates of reservoir unit tops and fluid contacts.

4. Net pay-thickness (apparent and TVTH) for units and total reservoir.

5. Reservoir units average porosities and water saturations.

7. Samples requirements

4.1 Samples from wells

1. Cuttings samples - representative, washed and dried samples, depth labelled, collected whilst drilling the well at selected intervals. Wherever possible each sample to be at least 100g weight. The collection of cuttings samples in the top hole section of development wells drilled from a single surface location may be waived following discussions with the DTI.

2. Slabbed cores - from all cores taken as a continuous vertical section comprising at least a width of the core, which will allow standard poroperm plugs to be taken.

3. Oil samples - a litre sample of stock tank oil to be taken from each tested horizon of new discoveries made since the issue of this notice with relevant test information such as oil gravity, GOR, associated gas composition, formation temperature and pressure plus sampling temperature and pressure.

NOTE : In the event that an operator wishes to dispose of any core material after the expiry of five years he should inform in writing the Head of Exploration and Licensing, Oil and Gas Directorate 2 (see address in section 10) giving six months notice in order that their preservation may be arranged if required.

Furthermore, if an operator is considering the disposal of any hydrocarbon fluid samples from discoveries made before the issue of this notice, such samples may be sent, giving notice, to the DTI Core Store in order to create a collection of UKCS oils.

4.2 Samples from the sea bed

Portions of sea bed samples and/or cores from boreholes penetrating below the sea bed are required.

8. Suspended wells returns

Previously, returns on suspended wells were sent on an annual basis to the Health and Safety Executive as part of the Agency Agreement with the DTI in respect to well consents. Returns should now be made to the DTI Well Consents Team, giving reasons for the continuation of suspension, or a date when the well will be abandoned.

9. Licence returns

The Regulations state that licence Returns should be made on geological work, including surveys and tests, wells drilled, and petroleum won and saved, on an annual basis (but see also PON 7, Reporting of Petroleum Production).

Returns should be made on a copy of the attached Proforma, and sent to the Licensing Administration Team.

Annual Returns (Proforma LR1) should be submitted within two months of the end of each calendar year.

10. Destination addresses

Department of Trade and Industry,
Oil and Gas Directorate,
Well Consents Team,
Location 215,
1 Victoria Street,
London SW1H 0ET
Tel. (020) 7215 5028
Fax. (020) 7215 6932

Department of Trade and Industry,
Oil and Gas Directorate,
Geoscience Information and Well Records Team,
Location 249,
1 Victoria Street,
London SW1H 0ET
Tel. (020) 7215 5181
Fax. (020) 7215 5070

Department of Trade and Industry,
Oil and Gas Directorate,
Licensing Administration Team,
Location 209,
1 Victoria Street,
London SW1H 0ET
Tel. (020) 7215 5095
Fax. (020) 7215 5070

Department of Trade and Industry,
Oil and Gas Directorate,
Data Management Team,
Location 271,
1 Victoria Street,
London SW1H 0ET
Tel. (020) 7215 5120
Fax. (020) 7215 5237

Department of Trade and Industry Core Store,
Hays Information Management,
376 Gilmerton Road,
Edinburgh EH17 7QS
Tel. (0131) 664 7330
Fax. (0131) 664 8394

PetroBank UK,
Suffolk House,
Pitmedden Road, Dyce,
Aberdeen AB21 0DP
Tel. (01224) 776177
Fax. (01224) 776171

Department of Trade and Industry,
Oil and Gas Directorate,
Exploration and Licensing Branch,
1 Victoria Street,
London SW1H 0ET,
Tel. (020) 7215 5046

The following forms are not intended to be submitted via the internet. Please print them out and submit them to the relevant postal address.

ANNUAL LICENCE RETURN (LR1)
to be furnished in respect of operations under exploration or production licences for landward or seaward areas.

This return should be submitted within two months of the end of the calendar year to:-

Department of Trade and Industry,
Oil and Gas Directorate,
Exploration and Licensing Branch,
Licensing Administration Team,
Location 209,
1 Victoria Street,
London SW1H 0ET.

Licensee ________________ Period ended__________________________ Licence Number E/P/EXL/PEDL___________

1. Geophysical surveys (List only work commissioned or carried out by the Licensee. In case of joint ventures give the name of the Operator)

* Seismic, Magnetic, Gravity, Geochemical, Airphoto, Geological, etc.

2.Drilling

**Stratigraphic, Exploration, Appraisal, Development.

***Producer: Drilling: Suspended: Temporarily Abandoned: Abandoned: Testing: Injection Gas: Injection Water:

3.Workovers using a rig

4.Particulars of petroleum encountered (not development horizons)

* Gas, Oil or Condensate

** Logging, mud samples, Cuttings, Cores, FIT, Formation test.

5.Particulars of water, mines, commercially significant coal or minerals encountered.....

6.Petroleum won and saved

(1) Field ____________________Quantities reported by PPRS Yes No

(2) Field ____________________Quantities reported by PPRS Yes No

All petroleum production should be reported monthly by the Petroleum Production Reporting System. For any production not reported in the PPRS, list below or attach full monthly details of well extraction quantities per field at standard conditions of 15°C and 1,01325 bar (1 atm.) expressed as metric tonnes or cubic meters of stabilised oil/condensate with density in kg/cu.m and gas/gaseous liquids in thousands cu.m both excluding water.

Date________________________ Signed______________________ Capacity_____________________

Back | Title | Table of Contents
Appendix 1 | Appendix 2 | Appendix 3 | Appendix 4 | Appendix 5 | Appendix 6 | Appendix 7 | Appendix 8 | Appendix 9
Appendix 10 | Appendix 11 | Appendix 12 | Appendix 13 | Appendix 14 | Appendix 15 | Appendix 16 | Appendix 17
Index Map | Plate 1 | Plate 2W | Plate 2E | Plate 3W | Plate 3E | Plate 4W | Plate 4E | Plate 5 | Plate 6
Plate 7 | Plate 8W | Plate 8E | Plate 9W | Plate 9E | Plate 10W | Plate 10E | Plate 11 | Plate 12 | Legend