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Skinfaks/Rimfaks IOR – Strong H orses in The Gullfaks Family

Skinfaks/Rimfaks IOR – Strong H orses in The Gullfaks Family. Sandsli, 8.februar 2005. Skinfaks/Rimfaks IOR (SRI) – strong horses in the Gullfaks family. Topics to be covered: Seismic amplitudes in exploration Existing technology to reduce cost and increase reserves

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Skinfaks/Rimfaks IOR – Strong H orses in The Gullfaks Family

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  1. Skinfaks/Rimfaks IOR – Strong Horses in The Gullfaks Family Sandsli, 8.februar 2005

  2. Skinfaks/Rimfaks IOR (SRI) – strong horses in the Gullfaks family Topics to be covered: • Seismic amplitudes in exploration • Existing technology to reduce cost and increase reserves • Production technology issues • Examples of flexibility built into the concept • Lessons learned Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

  3. The SRI team also matured the Gulltopp (Dolly) discovery to PDO level in 2003 Situation in year 2001: Rimfaks Brent: Production start year 2000. Spring 2001: IOR possibility documented, 2 infill wells + extra gas handling capacity gives 2.1 MSm3 of extra oil. GF Sør L+M templates, prod.start Sept.2001. 3 flowlines to GFC for GF Sør Brent gas production. Extra capacity and tie-in possibility at L/M for upsides in GF Sør Field. Prospects defined in the Brent Gp. and Statfjord Fm. in the Ole, Dole and Doffen (ODD) segments. (Later named Skinfaks.) Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

  4. Exploration well in ’Dole’(N3) and ’Ole’ (N2) segments drilled in spring, 2002 • Proven segments: N2 and N3 Upper Brent • Prospects: • N4 upper Brent. P(f): 97% • N5 upper Brent. P(f): 80% • N1 upper Brent. P(f): 90% • Prospects: • N4 lower Brent. P(f): 56% • N1 lower Brent. P(f): 46% (defined in 2004) • N1 Statfjord. P(f): 40 % • N4 Statfjord. P(f): 90% Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

  5. DG1, DG2 and DG3 are decision gates in Statoils project development model DG1 team establ. 33/12-8S DG1 (BoK) DG2 (BoV) DG3 (BoG) PDO del. Rimfaks Brent IOR Static (G&G) model used: 3D IRAP RMS (built 2001) Dynamic (res.) model used: 3D Eclipse 300 (PDO mod.) 3D Eclipse 300 (new model, built 2002) 3 -> 4 MSm3/Sd extra gas prod.rate 3. infill well, with DIACS Elements included in production strategy: - 2 infill wells. - 3 MSm3/Sd ekstra gas pr. - Gas reinjection, blowdown from oct.2010 (PDO strategy) Volume reduction (significant!) Skinfaks Static (G&G) model used: 2D IRAP Classic + GeoX 3D IRAP RMS Dynamic (res.) model used: Field analogue + MBAL models 3D Full Field Eclipse 100 (Brent reservoir) X Elements included in production strategy: - Water Injection - 5 conventional, horisontal wells. - Depletion Gas lift Segm.N1 UB incl. in ’basis’ DIACS compl. X - Gas Injection - Wells: 1 + 1 ML + 1 sidetr. - N1 UB and N4 Statfj. excl. from ’basis’ Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

  6. DG1 team establ. DG1 (BoK) 33/12-8S DG2 (BoV) DG3 (BoG) PDO del. Feasibility study phase DG1/BoK concept: A Gullveig Statfjord well was a part of the project in the DG1 and early DG2 phases. Later excluded. Project feasible. Establish project team. Go on with concept (screening) studies. Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

  7. DG1 team establ. Scr. ph. 1 Screen.phase 2 Scr. ph. 3 DG1 (BoK) 33/12-8S DG2 (BoV) DG3 (BoG) PDO del. Feasibility study phase 4 GF-concepts evaluated: GFC Gulltopp GFA ’A’ ’B’ Continue with optimising concept ’D’ for a final concept selection (AP1 – Approval point 1). ’C’ ’D’ L/M Skinfaks Rimfaks IOR Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

  8. For the SRI project: Skinfaks and Rimfaks wells prognosed with very different tubing head pressures • Impact on production profiles • Decision: Two flowlines instead of one, from the SRI prod.system. Wells and pipelines in a network PROJECT Discipline Leaders: Drilling, Well and Production Technology Petroleum Technology Facility (Subsea) Reservoir simulation Flow assurance ”Nodal analysis” Tools: OLGA GAP/PROSPER ECLIPSE W. NETWORK OPTION Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

  9. Which tasks do the other persons have ? Concept screening/selection How are my data used ? Design Basis Document Possibilities? Limitations? Consequences? Technical solutions The SRI Core Team • ”The Technical Forum”: • Project members from all engineering disciplines (Reservoir, ProTech, Drilling, Completion, Flow Assurance, Subsea, Pipeline,Topside) • A leader was appointed • Meetings were held regularly (every week) ”The SRI Technical Forum” Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

  10. DG1 team establ. Scr. ph. 1 Screen.phase 2 Scr. ph. 3 Scr. Ph. 4 DG1 (BoK) 33/12-8S DG2 (BoV) DG3 (BoG) PDO del. Feasibility study phase • 9 variants of concept ’D’ evaluated: • - 1 or 2 templates, 1 or 2 flowlines, with or without smart wells. • Selection criteria: • NPV (and then IRR and NPV/CAPEX discounted) • Robustness (drilling), and flexibility wrt. upside volumes To L/M Recommendation, AP1, end of october 2003: Concept ’3S’ (2 templates, 8 slots, 2 flowlines, smart wells (DIACS, one ML): BUT: Further work the following weeks weakens the project economy significantly: Cost increase (rock dumping, pilot well in segm.N4), delayed prod.start (Jan.06 => Oct.06). Recommendation from Project end of November.2003: Postpone DG2/BoV. Improve concept and economics. ’Upside’ well ’Basis’ well Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

  11. DG1 team establ. Scr. ph. 1 Scr. Ph. 5 Screen.phase 2 Scr. ph. 3 Scr. Ph. 4 DG1 (BoK) 33/12-8S DG2 (BoV) DG3 (BoG) PDO del. Feasibility study phase • 11 variants of concept ’SRI to GFC via L/M’ (re)evaluated: • - 1 or 2 templates, + 1 or 2 satellites, 1 or 2 flowlines. • - Further optimising of subsea wellhead locations and subsea/pipeline cost. • - Increased volumes (3.RF well, Skinfaks N1 segment, Skinfaks gas lift) • Upside volumes quantified, value (risked) calculated. • Selection criteria: NPV (and then IRR and NPV/CAPEX disc.) To L/M Recommendation from Project, February 2004: Optimise concept ’2SX’ (1 template, 1 satellite, 2 flowlines) further towards DG2. ’Upside’ well ’Basis’ well Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

  12. DG1 team establ. Scr. ph. 1 Scr. Ph. 5 Screen.phase 2 Scr. ph. 3 Scr. Ph. 6 . Scr. Ph. 4 DG1 (BoK) 33/12-8S DG2 (BoV) DG3 (BoG) PDO del. Feasibility study phase • Discussion with partners on ’low cost’ alternatives: • Early in the concept selection phase (spring 2003), alternatives for SRI based on re-use of existing infrastructure (I, J, K templates) were briefly reviewed from the operator and put behind for specific reasons, but without any formal process or documentation. • Now, license partners want to compare concept 2SX with other alternatives, making use of existing infrastructure: • 38 (!) combinations/variants were evaluated • Screening criterion: NPV. In addition: Relative value (NPV/CAPEX disc.), IRR, technical maturity and risk, and flexibility for realising upside volumes. Partners approved concept 2SX (AP1/DG2), September 2004 Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

  13. After AP1, your influence on the concept as subsurface engineers is very much reduced. Statoil’s Project Development Model, Planning Phase: In Statoil’s governing documentation (AR05 ++) the focus on AP1 seems less than on the formal approval point DG2 (provisional project sanction). At AP1, concept selection point: Important with a good picture of the resource potential in the area. Formal requirements for uncertainty analysis on volumes and production profiles. Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

  14. PDO delivered Dec.2004 • PDO approved Feb.2005 This development benefits from flexibility in existing infrastructure Providing additional connection points for potential future developmentsat a low pre-investment cost

  15. Reserves and CAPEX (cut-off year 2020) (CCE-2 is last project update, per September 2005) Results, CCE2 (upd. cost, plan and volumes) NPV in MNOK05 has increased with a factor of 3-4 since the PDO - 1/3 of effect due to increase in oil production volumes - 2/3 of effect due to increased prices on oil and gas Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

  16. Skinfaks/Rimfaks IOR – strong horses in the Gullfaks family Lessons learned: • Combining infill drilling (IOR) and new disoveries can make a profitable project. • Involve the license group EARLY in the concept selection phase. • Document also ‘obvious’ choices wrt. concepts screended out. • The focus on the concept selection point (AP1) should be stronger in Statoil’s governing documentation, wrt. line and partner involvement. • Create a technical forum for continuous, cross-disciplinary discussions ‘on working level’ (not only at core team level). • Define and place the ‘system responsibility’ role early. Make sure that various models (wells - pipeline network) are consistent. • Strive to get flexibility included in the concept. It will most certainly pay off! Skinfaks/Rimfaks IOR. RES/PRO-seminar, 23.-24.November 2005.

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