随后的电缆测井和流体取样证实，在约 3370 米的气水接触面上方存在活气柱，该气水接触面位于 B-Sand 的中部，是整个 Leman Sandstone 部分的关键生产层段。Selene 勘探区的最新井后结构图显示，最大气柱约为 100 米。

初步迹象表明，这是一种高品质干气，典型产自邻近油田，且未含有 H2S。

根据从钻井现场获得的初步信息，Deltic 更新了 Selene 发现的体积模型，目前估计 Selene 包含的总 P50 预计最终可采资源量（或“EUR”）为 1310 亿立方英尺^（ P90-P10 范围为 950 至 1760 亿立方英尺^），处于钻探前估计值的低端。

然而，大部分可采资源集中在 48/8b-3Z 井位置质量更高的 B-Sand 上倾区，这应该支持一种更简单、更便宜的开发方案，并且每个井的天然气产量将高于发现前的预想。

更深的构造顶和更浅的气水接触面相结合，导致整个构造的气柱高度降低。目前认为，B 砂层底部和大部分下层 C 砂层位于构造东南部的水柱中，而井中更深的气体读数现在被解释为残余气体，而不是活气柱。

该井已证实，井位处的 B 砂储层性质接近钻探前预测范围的高端。该井遇到的 B 砂厚度为 53 米（钻探前 P50 为 47 米），平均孔隙率为 12.1%（高于钻探前的 11% P50），含气饱和度与钻探前的预期一致。

这些改进的储层特性得到了井下测试的支持，该测试回收了气体样本，并表明渗透率在气水接触面以上 1 至 5 mD 范围内。这些孔隙度和渗透率属性支持在更新的体积模型中使用更有利的 B-Sand 采收率。

如前所述，该井并非为适应常规地面流动测试而设计的，并且支持潜在未来开发计划和投资决策所需的所有油藏数据均已通过该井成功获取。

预计钻机将于下周末拆除，之后将对电缆数据、岩心样本、流体样本和压力测试数据进行详细分析，以进一步完善地质模型、体积估算和拟议的开发计划。

根据油井的勘探结果和收集到的数据，Deltic 认为合资公司应该能够顺利推进油田开发规划，并就未来开发做出最终投资决策，而无需进一步进行评估井。

除了Selene以外，Deltic还将重新评估位于该区块东北角的Endymion矿区，这是另一个低风险的莱曼砂岩矿区，可能与未来的Selene开发项目有关。

随着合资公司更新开发计划，三角洲地区将重新评估其经济模型，但钻探前的模型表明，在2024年10月30日预算中宣布的财政制度下，可采储量超过1000亿立方英尺的油气储量^仍将具有经济可行性，并最终为三角洲地区带来实质性的正现金流。

首席执行官 Andrew Nunn 评论道：“地下专业知识是 Deltic 股权故事的核心，也是我们最近为公司制定的战略方针的核心。在此背景下，Selene 油井的成果总体上是不错的，将 Deltic 的勘探成功记录从 2 次扩大到 2 次。虽然我们预测可采储量处于钻探前估计值的低端，但 B-Sand 质量的提高和资源集中度的提高应该能够支持更简单的开发，并由于资本支出和运营支出要求的降低而提高经济效益。

我们期待与壳牌和 Dana 合作，进行常规的钻井后分析并制定计划，推动 Selene 油田在未来一年内得到开发。我们仍然相信该资产可以为我们的股东创造重大价值。”

在线阅读文章：https://www.oilfieldtechnology.com/exploration/31102024/deltic-energy-confirms-gas-discovery-at-north-sea-selene-prospect/

Subsequent wireline logging and fluid sampling have confirmed the presence of a live gas column above a gas-water contact at c. 3370 m which is in the middle of the B-Sand, the key producing interval within the overall Leman Sandstone section. Updated post-well structural maps of the Selene prospect point towards a maximum gas column of c. 100 m.

Initial indications point towards a high-quality dry gas, typical of production from adjacent fields, with no reported H2S.

Based on the preliminary information available from the wellsite, Deltic has updated its volumetric model of the Selene discovery and now estimates Selene to contain gross P50 estimated ultimate recoverable (or 'EUR') resources of 131 billion f³ (P90-P10 range of 95 – 176 billion f³) which is at the lower end of pre-drill estimates.

However, the bulk of the recoverable resources are concentrated in the higher quality B-Sand up-dip from the 48/8b-3Z well location which should support a simpler and cheaper development option with greater gas production per well than was envisaged pre-discovery.

The combination of a deeper structural crest and a shallower gas water contact has resulted in reduced gas column heights across the structure. The base of the B-Sand and most of the underlying C-Sand are now believed to be in the water leg across the south-eastern part of the structure, with the deeper gas readings from the well now interpreted as residual gas rather than a live gas column.

The well has confirmed that the B-Sand reservoir properties at the well location were towards the high end of the ranges predicted pre-drill. The B-Sand encountered in the well was 53 m thick (pre-drill P50 of 47 m) with an average porosity of 12.1% (up from 11% P50 pre-drill) and a gas saturation in-line with pre-drill expectations.

These improved reservoir characteristics are supported by a downhole test, which recovered gas samples, and indicated permeabilities in the range of 1 – 5 mD above the gas-water contact. These porosity and permeability attributes support the use of more favourable recovery factors for the B-Sand in the updated volumetric model.

As previously indicated, this well was not designed to accommodate a conventional surface flow test and all of the reservoir data required to support a potential future development plan and investment decision has been successfully acquired through this well.

Following demobilisation of the rig which is expected towards the end of next week, there will be a period of detailed analysis of wireline data, core samples, fluid samples and pressure testing data which will further refine the geological model, volumetric estimates and the proposed development plan.

Based on the results of the well and the data collected, Deltic believes that the JV should be well placed to progress towards field development planning and a final investment decision on a future development without requiring a further appraisal well.

In addition to Selene, Deltic will re-evaluate the Endymion prospect, located on the north-eastern corner of the block, which is another low-risk Leman Sandstone opportunity that could be tied into any future Selene development.

As the JV updates the development plan Deltic will re-assess its economic models, however pre-drill modelling indicates that volumes over 100 billion f³ recoverable will remain economically viable, and ultimately produce material positive cash flows for the Deltic, under the fiscal regime announced in the budget on 30 October 2024.

Andrew Nunn, CEO, commented: "Subsurface expertise lies at the heart of the Deltic equity story and remains central to the strategic approach we recently laid out for the Company. In this context, the outcome of the Selene well is a good result overall and extends Deltic's exploration success record to two from two. Although we are predicting recoverable volumes at the lower end of pre-drill estimates, the improved quality of the B-Sand and increased resource concentration should support a simpler development with enhanced economics due to reduced CAPEX and OPEX requirements.

We are looking forward to engaging with Shell and Dana as we work through the customary post-well analysis and preparation of a plan which will move the Selene discovery towards development over the coming year. We continue to believe that the asset can create material value for our shareholders."

Read the article online at: https://www.oilfieldtechnology.com/exploration/31102024/deltic-energy-confirms-gas-discovery-at-north-sea-selene-prospect/