Oil and Gas ConsultancyOil and Gas Consultancy
Our field development planning work tends to require the deployment of our full INTEGRATED team and covers all activities required in the development of a field. In essence through conducting our geophysical, geological, reservoir, facilities and economic assessments we seek to produce the optimum plan for production of a given field. The level of work required in such an assessment varies ranging from outline to the development of detailed plans for submission to government bodies for consideration. Below are details of the consulting work carried out in this area.
The projects below have required deployment of Field Development Planning skill set:
Updated an integrated reservoir model developed previously for the Client for this offshore oil field in thePolish sector of the Baltic see. The original model used an Eclipse compositional simulator as its basis. Converted the original integrated model to a Black Oil model, history matched past production including production that had been experienced since the development of the original model.
Once the new model was established went on the model a number of production alternatives to advise the Client if his proposed early production scenario was feasible. Also determined if early production would have a detrimental effect on ultimate recovery from the field.
Acted as Independent Consultant during the Client’s development of financing solutions to fund future operations. During execution of the work performed a number of services:
Assisted the Client in marketing the project to a number of potential farminees and loan providers.
Developed an independent reserves assessment for four newly discovered fields in this ultra deep water license area in Nigeria in conformance with the PRMS standard. Carried out full seismic interpretation, prepared a reservoir assessment and production profiles, developed outline field development plans and also conducted a full development and operating cost assessment using our NETCO$TER cost Evaluation Software.
The discoveries are located in ultra deep water depths and required the use of innovative productions solutions in the development scheme. Based on the commercial terms associated with the acreage and the technical and cost assessment described above developed an independent valuation of the discoveries.Also carried out a full prospectivity assessment of the acreage based on recently acquired 3D seismic data. The work was conducted as part of a farm-out process which is now complete. The Client disposed of a major portion of his 100% holding in the Block.
Carried out a reserves verification to PRMS standards as part of a technical due diligence assessment of this complex gas condensate field complete with oil rim located in the Norwegian sector of the North Sea. Also carried out a risk assessment on well performance, project schedule and project costs. Advised the client on technical risks associated with the project and the banking case profiles that should be adopted.
Carried out the upstream section of gas utilisation study designed to establish if implementation of an early gas power generation scheme in the license area was technically and economically feasible.Developed a reservoir simulation model for the discovered fields and established a field development plan for the production of gas suitable for power generation.The plan included a scheme to recover associated liquids and to produce LPG for local consumption. Carried out costing and economic analysis of the upstream scheme to establish the optimum production scheme. Development and operating costs were generated using our NETCO$TER cost Evaluation Software.
Carried an analysis of international Oil and Gas Mega-projects for a National Oil Company. The work sought to establish how government bodies particularly national oil companies interacted with international oil companies carrying out very large projects in their countries. The work focused on establishing:
• How government bodies organised themselves with respect to such projects
• The procedures and strategies adopted by government entities in controlling such projects
• The relative performance of such projects in various area around the world.
The work focused on four geographic regions: Western Europe, Middle East, South America and South East Asia
Assisted a Client looking to acquire a share in of a number of assets in western Kazakhstan, in the Pre-Caspian Basin and the Mangyshlak. Carried out full technical and economic evaluations of each asset including: seimic interpretation verification; geological model validation; development of independent PRMS assessment including 1P, 2P and 3P reserves and contingent resources; review of detailed Field Development Plans (in Russian); detailed cost verification of development and operating costs using our NETCO$TER cost Evaluation Software; asset valuation including Net Present Value and Fair Market Value - the latter was based on Bayphase'proprietary data base of Kazakhstan oil field equity transactions. Assisted the Client in making his acquisition decisions and development of his acquisition strategy.
Carried out a technical assessment of revisions to the field development plan proposed for this turbidite field offshore Ivory Coast in water depths greater than 1,500m. Critically assessed well design and sand screening solutions in light of well failures. Established financing basis through the determination of banking case profiles.
Developed independent probabilistic reserves assessment for this field in Poland's sector on the Baltic Sea in accordance with PRMS standard. This field is a small clastic structure with relatively homogeneous rock types and properties. Developed a fully integrated geological and reservoir simulation model for the field. The work included full assessment and interpretation of a 3D seismic data set, development of a static geological model and a dynamic reservoir model. Carried our modelling to determine optimum configuration through consideration of gas export with water injection support, gas re-injection with water injection support and water alternating gas injection alternatives for the field. Also carried out conceptual field development planning to determine the associated surface production scheme. Special features considered included correct modelling of miscible gas injection using PVT analysis and extrapolation of a range of PVT tests. Prepared a reserves certification statement in accordance the PRMS standard.
Developed an independent probabilistic resources and reserves assessment for this offshore block in Tunisia in accordance with the PRMS standard. Also carried out a valuation of the block for potential equity purchase by the Client. The valuation was based on development and operating cost estimates established independently by our consultants.
Carried out a study to establish to optimum field development plan for a number of prospect outcomes in this deep water license bock – offshore Oman. Reviewed both oil and non-associated gas potential outcomes, developed outline Field Development Plans and carried out economic assessments to determine the optimum configuration.
The exploration prognosis was that outcomes could range from small to medium sized oil fields through to medium sized non-associated gas fields. Developed range of potential reserves and then established viable field development plans for each reserve size. Prospects were sited close to shore in 3,000m water depth; fully costed each development plan using Bayphase's cost estimating tool - NetCo$ter.
Developed the formal submission to the government of Oman.
Developed a reserves assessment in line with the PRMS standard and outline field development plans for two onshore non-associated gas fields in Nigeria. The work also included a full capital and operating cost assessment developed using our NETCO$TER cost Evaluation Software.
Developed independent deterministic and probabilistic reserves assessments for these prospects in accordance with the PRMS standard. These prospects are significant clastic structures in Kazakhstan sector of the Caspian Sea.Developed fully integrated geological and reservoir simulation models for the prospects – 6 in total. The work included full assessment and interpretation of an extensive 3D seismic data set shot over a license area , development of a static geological model and a dynamic reservoir model. Carried our modelling to determine optimum production configuration for the prospects through consideration of water injection and gas injection schemes. Also carried out conceptual field development planning to determine the associated surface production scheme.
Prepared resource certification statements in accordance the PRMS standard and in accordance with regulations set down by Kazakhstan’s State Reserves Committee.
Developed an independent probabilistic reserves assessment for this field in western Siberia (Russia) in accordance with the PRMS standard. Also prepared bank case production profiles which were used in valuing the property for financing purposes.
Developed a reserves verification for these fields located in Nigeria in accordance with the PRMS standard and based on reserves reports submitted by other consultants. Also prepared bank case production profiles which were used in valuing the property for financing purposes. The work included vetting the owner’s field development plan for cost and schedule risk; an itemisation of the risks and their potential cost/financial impact was developed.
Developed independent deterministic and probabilistic reserves assessments for this field in accordance with the PRMS standard. This field is a giant carbonate structure with significant quantities of highly sour gas (33.5% H2S and 9.6% CO2).
Developed integrated geological and reservoir simulation model for the field. The work included full assessment and interpretation of a 3D seismic data set, development of a static geological model and a dynamic reservoir model. Carried out modelling to determine optimum configuration through consideration of acid gas injection, desulphurisation and power generation alternatives. Also carried out conceptual field development planning to determine the associated surface production scheme. Used our NETCO$TER cost Evaluation Software to prepare detailed development and operating costs
Special features considered included: potential disposal of separated sour gas into the host reservoir and through enhanced recovery schemes in associated independent reservoirs; design of equipment to handle highly toxic hydrogen sulphide concentrations; impact of high hydrogen sulphide levels on gas physical properties.
Prepared a reserves certification statements in accordance the PRMS standard.
Developed independent probabilistic reserves assessment for this field in the Caspian Sea in accordance with the PRMS standard. This field is a very large post-salt clastic structure with multiple and varying production horizons.Developed a fully integrated geological and reservoir simulation model for the field. The work included full assessment and interpretation of a 3D seismic data set, development of a static geological model and a dynamic reservoir model. Carried our modelling to determine optimum configuration through consideration of water injection support and gas re-injection alternatives. Also carried out conceptual field development planning to determine the associated surface production scheme.
Special features considered included correct modelling of multiple production layers and sand qualities.Prepared a reserves certification statement in accordance the PRMS standard. Also prepared a reserves statement in accordance with regulations set down by Kazakhstan’s State Reserves Committee.
Carried out a review of a major revision to the plan to develop a giant onshore gas condensate field development plan to assess:
Developed independent deterministic and probabilistic reserves assessments for this large gas condensate discovery in Kazakhstan’s sector of the Caspian Sea; the probabilistic assessment was developed in accordance with the PRMS standard. Also prepared outline field development plan and made an evaluation of appraisal, development and operating expenditures for an economic assessment .
Conducted a field development planning audit for the upstream development of this project in Qatar. This consisted of offshore production platforms, offshore pipe lines and an onshore gas processing facility. Vetted the technical basis for the project also audited the development cost of project and associated budgets. Made recommendations for future development of the project designed to reduce cost. Cost analysis was based on Bayphase's cost estimating tool - NETCO$TER.
Performed a reserves verification and carried out a valuation for this offshore field in Nigeria. Carried out the verification to the standards set by the PRMS. The valuation was carried out following a field development planning assessment designed to establish the optimal modifications and in-fill drilling required to fully develop the property. Development and operating cost estimates were generated as the basis for the valuation.
Developed the field development plan for next phase of development of these two giant fields. Plan was developed in conjunction with the Clients senior personnel and for two timescales long term 5-year forecast and short term 1 year forecast. Developed annual budgets for all capital operating expenditures for the field over a two year period – current year and the following year. Cost estimates were based on evaluations performed independently by our consultants.
Carried out a screening study for a relatively large onshore non-associated gas field in Indonesia. A key element of the study was to assess the optimum method for production of this field which had a significant hydrogen sulphide content – 1mol%. The optimisation was based on plant designed to treat 200 million standard cubic feet of raw gas. Development and operating cost estimates were generated using our NETCOSTER Cost Evaluation Software.
Developed independent deterministic and probabilistic reserves assessments for this giant field in Kazakhstan accordance with the PRMS standard. This field is a super giant carbonate structure that is significantly overpressured
Developed a fully integrated geological and reservoir simulation model for the field. The work included full assessment and interpretation of a 2D seismic data set, development of a static geological model and a dynamic reservoir model. Carried our modelling to determine optimum configuration for a gas re-injection scheme. Also carried out conceptual field development planning to determine the associated surface production scheme.
Special features considered included: fracture modelling and prediction to determine potential contribution to reserves; analysis of Soviet era well tests, well logs and seismic data
Prepared reserves certification statements in accordance the PRMS standard and in accordance with regulations set down by Kazakhstan’s State Reserves Committee.
Carried out a screening study for a small potential offshore development in Libya. The field had a hydrogen sulphide content of 2.0 mol% and reserves of 40 million barrels. A key element of the study was to assess how this development would interface with an existing onshore treatment plant. In addition the study sought to establish the optimum balance between onshore and offshore facilities. Development and operating cost estimates were generated using our NETCO$TER cost Evaluation Software.
Carried out a screening study for an exploration license in the Central Graben of the UKCS. A range of potential prospects were evaluated including small oil fields of 20-30 million barrels recoverable and gas condensate of .3 Billion Standard Cubic Feet with associated liquids. The study’s key objective was to establish if economic solutions could be established for development of these relatively small prospective fields. Development and operating cost estimates were generated using our NETCO$TER cost Evaluation Software.
Carried out a screening study for a newly discovered field onshore Libya in the Sirte basin. A range of potential prospective oil field sizes were evaluated ranging from 10-300 million barrels recoverable. The study’s key objective was to establish if economic solutions could be established for development of these relatively small recoveries at the lower end of the assessment. Development and operating cost estimates were generated using our NETCO$TER cost Evaluation Software.
Carried out a screening study for a newly discovered field in a shallow water section of the Niger delta. A range of potential prospective oil field sizes were evaluated ranging from 20-100 million barrels recoverable. The study’s key objective was to establish what was the most economic solution for the field’s development: fixed platform or FPSO. Development and operating cost estimates were generated using our NETCO$TER cost Evaluation Software.
Carried out a screening study for a relatively large offshore sour gas field in Indonesia with reserves of 0.5 Trillion Cubic Feet and a hydrogen sulphide content of 1.2 mol%. A key element of the study was to assess the optimum balance between onshore and offshore facilities. Development and operating cost estimates were generated using our NETCO$TER Cost Evaluation Software.
Carried out a screening study for a relatively large onshore acid gas field in Nigeria with reserves of 1.5 Trillion Cubic Feet and Carbon Dioxide content of 4.6 Mol%. A key element of the study was to assess the optimum method for reduction of Carbon Dioxide concentrations to levels that would allow the gas to be processed in an existing LNG facility. Development and operating cost estimates were generated using our NETCO$TER Cost Evaluation Software.
Carried out a screening study for a small potential offshore development in Morocco. The field contained heavy oil with a density of 9 – 15 °API and reserves of 30 million barrels. A key element of the study was to assess how development techniques used in North Sea fields might be adapted and used in this case. The study assessed a number of fixed platform and floating production solutions. Development and operating cost estimates were generated using our NETCO$TER Cost Evaluation Software.
Carried out a screening study for an exploration license in the Central Graben of the UKCS. A range of potential oil field prospects were evaluated ranging from 25 through to 100 million barrels recoverable. The study’s key objective was to establish if economic solutions could be established for development of these relative small prospective field sizes using Floating Production Technology. Development and operating cost estimates were generated using our NETCO$TER Cost Evaluation Software.
Carried out a screening study for a small potential offshore development in China local to Hong Kong. The field contained a light volatile oil with a density of 44 – 46 °API and reserves of up to 30 million barrels. A key element of the study was to assess a number of fixed platform and floating production solutions the field to determine the economic optimum. Development and operating cost estimates were generated using our NETCO$TER Cost Evaluation Software.
Carried out a screening study for a small potential offshore HPHT development in the Central Graben of the UKCS. A range of potential reserves outcomes were consider from 10 million barrels and 36 billion standard cubic feet through 40 million barrels and 144 billion standard cubic feet. A key element of the study was to assess whether an economic justification could be developed for low reserves cases that under pinned the case for further appraisal drilling. Development and operating cost estimates were generated using our NETCO$TER Cost Evaluation Software.
Carried out a screening study for a relatively large onshore non-associated gas field in Bangladesh with reserves of 1.0 Trillion Cubic Feet. A key element of the study was to assess the optimum method for production of this field which had a significant level of associated liquids: depletion, recycling and depletion with compression. Development and operating cost estimates were generated using our NETCO$TER Cost Evaluation Software.
Carried out a screening study for a significant gas gathering facility in the UKCS. Located in the Central North Sea the system would be designed to gather gas from a number existing fields through a gathering system comprised of two platforms. Platform configuration would comprise a gathering and compression platforms designed to maintain production from the area for an extended period. A key element of the study was to optimize gathering and export pipe lines configurations along with production throughput; production rate of 900 through 1,300 million standard cubic feet per day were considered. Development and operating cost estimates were generated using our NETCO$TER Cost Evaluation Software.
Carried out a screening study for a medium sized onshore gas condensate field in Nigeria with reserves. The assessment focused on establishing the size and cost of facilities required for liquids production scenarios ranging from 30,000 through 50,000 barrels per day. The study was designed to establish the economic optimum production rate based on price constraints including restricted local market for sale of associated gas. Development and operating cost estimates were generated using our NETCO$TER Cost Evaluation Software.
Carried out a screening study for production of a significant gas field offshore Angola. Due to the deep water location of the field and the clients preference for dry wellhead technology the development plan used Tension Leg Platforms as its basis. The field was assumed to be developed in three phases; two depletion phases with a combined production rate of 750 million standard cubic feet per day and a compression phase of 550 million standard cubic feet per day. The facilities also included the phased development of an onshore gas reception terminal. Development and operating cost estimates were generated using our NETCO$TER Cost Evaluation Software.
Bayphase
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