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Drilling Programme - checklist

checklist

General Information

  • File name and location
  • Well Name
  • Classification
  • Country
  • Concession
  • Ground Level
  • Surface Location: Lattitiude ___ N, Longitude ___ E
  • Surface Coordinates: Field ___ N, Field ___ E
  • Seismic Line
  • Cost Centre
  • Planned Total Depth
  • Rig
  • Objective (top Hydrocarbon)
  • Target Coordinates and Tolerances
  • Coring requirements

Casing Programme Summary

  • Hole size / Depth / OD / Wt / Grade / Coupling / Top Cement

Mud Programme Summary

  • Hole size / Mud type / Density

Logging Programme Summary

  • Hole size / logging programme

Coring Programme Summary

  • Hoe size / Formation / depth

Possible Drilling Problems

  • Hole size / Problem

Approvals

  • Name / Position / Signature / Date

Detailed Programme

General Planning Notes:

This section should describe the general planning notes:

  • This programme is a guide to help ensure that safe and efficient operations are carried out. The Drilling Supervisors must review this programme and suggest appropriate changes to further enhance safety and efficiency.
  • Any changes to the programmed activities should be discussed with and approved by the Drilling Superintendent.
  • In order to capture the information while the well is being drilled, the Drilling Supervisors will are to meet the following requirements:
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    • A daily diary is to be kept. This will record informal notes on drilling the well, including ideas and recommendations for improving operations on the following well. This will ensure that data not traditionally recorded by the daily reporting systems but that will be valuable for future well planning will not be lost. Information is especially required on each formation encountered; recommendations for improved bit/BHA selection, particular drilling practices etc.
    • The diary must also record the reasoning behind decisions made on the rig which affect drilling operations. Decisions such as which bit to run, or why to wiper trip (if different to this well programme) must be justified with an engineering analysis showing the expected benefits of the change.
    • At the end of a hitch each Drilling Supervisor will write a short, informal report for the office which can be used as the basis for the final well report. This will give specific details on problems encountered (how solved and recommendations to avoid or mitigate those problems on future wells), reasons behind decisions made on the rig and anything else that is relevant to evaluating drilling performance.
  • A separate file (“Notes for Drilling Supervisors”), will contain information on daily drilling reports, cost reporting, mud inventory etc and general advisory and contact information.
  • Any changes to the approved drilling programme will be documented using the Management of Change procedure.
  • Operations are to be carried out safely, in accordance with good oilfield practice and in compliance with the Company Drilling and Technical Manuals, unless dispensation has been granted from the Drilling Manager. Operations should be executed to minimise adverse impact on the environment.
  • Drillstring components are to have been inspected to API RP7G prior to running in the hole. Ensure that all drillcollars have stress relief grooves and are bored back, steel DC’s are to be spiral.
  • The programme should make reference to the offset wells applicable: Well Name / Approx Surface Distance / Approx Direction /
  • Depths given in this programme are in metres BRT.  RT elevation is assumed to be Xm above MSL.
  • Shallow gas review based on seismic surveys and offset wells.
  • Minimum stocks to be kept on site during drilling; 100MT Baryte, 500 SX LCM and 1000 SX cement.
  • Leakoff tests will be performed after drilling out all casings where a BOP is in use.
  • Measure mud density with both Pressurised and Atmospheric balances and record this at 15 minute intervals while drilling for mud in the pits and at the flowline, for all sections below the surface casing.  Use the pressurised balance measurement for maintaining the correct mud density.
  • Floats should have a small hole in them to allow drillpipe fillup while RIH and to allow direct readout of DP pressure if we get a kick.  The float will still be effective against heavy backflow and will enhance safety while tripping.
  • Amendments to this Drilling Programme will be sent from the Drilling Office from time to time.  For minor changes which do not impact on the well design and do not have serious operational impact, this will be approved by the Drilling Superintendent.  For larger changes, some or all of the original signatories may sign.

Pre-spud: positioning and anchor operations

Drilling Operations

Planning for each hole section:

  • Drilling Practices
  • Kick Tolerance at TD for expected pore pressure and fracture gradient
  • Any special notes or requirementsReporting requirements (daily and post-well);
  • Monitoring cavings levels and sampling / describing / preserving cavings;
  • Mud sampling requirements (times, sample sizes, how preserved etc);
  • Mud gradients, types, required properties, pH, test requirements, any special requirements (such as shale inhibition);
  • Wellbore Stability requirements;Potential ProblemsMud - formation requirements;
  • Solids Control requirements.
  • Recommended Bits and BHA’s
  • Hydraulics

Operational Sequence

  • Describe here the sequence of operations

Directional/ Deviation Programme

  • Vertical or deviated well;
  • Kickoff depth;
  • Build/drop/turn rates with inclinations, azimuths and depths to define complete wellpath;
  • Target depth, co-ordinates and boundaries;
  • Horizontal displacement and azimuth of target;
  • Target constraints showing the actual target area that would be acceptable, outside of which would be unacceptable;
  • Total well depth MD and TVD;
  • For a horizontal well, more information will be required such as final hole section azimuth, whether geosteering is to be used etc.;
  • Surveying requirements; types of tool at which stages, distance between surveys, computing method to be used, magnetic variation for the area;
  • For a well of more than 25 maximum planned inclination or with high anticipated dogleg severities:Drag and torque calculations, used to optimise the wellpath if necessary. Casing wear predictions, used to specify what precautions may be necessary (such as protector types & quantities, heavy wall casing at critical points, special monitoring).
  • Any relevant data on offset well paths which may affect the planned well.
  • Hole and bit sizes with section depths (including pilot hole sizes where applicable).
  • Proposed bits and BHAs together with recommended drilling parameters and performance expectations.

BOP equipment and testing

  • Diverter / BOP configuration for each hole section;
  • BOP test requirements;
  • Drills required;
  • Kick tolerance calculation assumptions made (eg state how much higher overpressure would be vs mud gradient);
  • Acceptable levels of influx after kick tolerance calculated;
  • Any special precautions (eg controlled ROP at certain points, flowchecks, increased kick drills etc);
  • Shut in procedures required;
  • Leakoff or limit tests to be used and procedure;
  • Minimum value of EMG and action to take if not attained.

Conductor, Casings and liners

Conductor

  • If driven: Size, weight, grade, connections, minimum setting depth, final blow count, final blow count; Type of hammer.
  • If drilled and Cemented: Size, weight, grade, types, connections, setting depths, centraliser requirements, single or multistage, additional jewellry;
  • Notes on any potential problems running casing and how these can be mitigated.
  • Notes on any potential high casing wear problems;
  • Reporting requirements (by job and post-well).

Surface and Intermediate casing/ Liner

  • Size, weight, grade, types, connections, setting depths, centraliser requirements, single or multistage, additional jewellry;
  • Notes on any potential problems running casing and how these can be mitigated.
  • Notes on any potential high casing wear problems;
  • Reporting requirements (by job and post-well).
  • Liners - type of liner hanger, will tieback packer be required, whether to be rotated &/or reciprocated during displacement;

Cementing (each hole section/ plugs, etc...)

  • Anticipated BHST, BHCT profile for the well
  • Reporting requirements (by job and post-well);
  • Cement tops, types of cementations, slurry types, gradients, special requirements;
  • Plugs to be used;
  • Mix water types, additives;
  • Mix methods for each slurry;
  • Anticipated slurry densities and yields;
  • Compatibility between mud, spacers and cement;
  • Estimated cement volumes (could state as % over gauge or % over caliper);
  • Specific advice on obtaining maximum mud displacement including required mud properties prior to cementing, spacers, flushes, scavenger slurries, any reciprocation or rotation during displacement, displacement regime;
  • 24 hour compressive strength;
  • Minimum pumpable time.

Wireline Logging & Petrophysics

  • Required logs (from subsurface department);
  • Required logs (Drilling Department requirements for drilling evaluation);
  • Sidewall sampling, formation sampling (RFT/MDT), coring requirements;
  • Cement logs;
  • Penetration logs;
  • Reporting requirements (daily and post-well).

Mud Logging

  • Sampling and preservation methods required for cuttings, cavings, mud, produced fluids, metal etc.;
  • Recording requirements and formats;
  • Type of unit (eg off or online);
  • Monitoring services required, types of alarms / alerts, routine calculations (eg monitor current kick tolerance, Dexponent etc);
  • Reporting requirements (daily and post-well).

Well Completion/Testing

  • Normally, detailed completion / testing programmes will be sent out closer to the time.  General notes should be made to allow some preparation to take place.
  • Precompletion requirements anticipated (eg bit/scraper runs, gravel packs, fracs, screens, packer setting, completion fluid specifications);
  • Tubing sizes and surface wellhead configuration;
  • General list of types of downhole completion / testing tools to be run with the completion tubing (eg side pocket mandrels, safety valves, packers);
  • Reporting requirements (daily and post-well).

Well Suspension / Abandonment

  • Anticipated well configuration on rig departure (diagram useful);
  • Zonal isolations required;
  • Whether casing will be cut and pulled;
  • Cement plugs & permanant bridge plugs depths etc.;
  • Whether suspension caps will be required;
  • Refer to Government and Company regulations or policies concerning abandonments;
  • Reporting requirements (daily and post-well).

Geological Prognosis

  • Expected lithology sequence with names and descriptions of formations, also information on anticipated hole problems (e.g. fractured, sloughing, washouts etc.);
  • Anticipated pore pressure and fracture gradients with depth - note also the level of confidence in the figures given;
  • Geological characteristics of expected formations; permeability, fluid type, hydrocarbon depths, gas zones etc.

Attachments

  • Offset Bit Records
  • Offset Hole Section Summaries
  • Logistics and Materials Ordering
  • Time - Depth and Cost Graph
  • Anticipated Well Lithology