Pantheon Resources plc (AIM:PANR, OTCQX: PTHRF)（“Pantheon”或“公司”）是一家石油和天然气公司，正在阿拉斯加北坡开发靠近管道和交通基础设施的科迪亚克和阿普油田。该公司今天将在 Sequire 投资者峰会上发表演讲。该公司将概述 Megrez-1 井的测井、岩心和岩屑分析结果，以及随之而来的阿普东部顶集资源的预期升级。该公司还将提供其流量测试计划的最新信息。

要点 ·

总烃柱垂直厚度增加至 2,310 英尺 (“TVT”)：对日志、岩心和岩屑的进一步分析（使用 AHS Baker Hughes 的 VAS 服务）表明，Megrez-1 已与比最初确定的更大的烃液柱相交 ·

四个最初确定的油层中潜在的 15% - 50% 资源升级：将增加的净产层厚度合并到 670 英尺 (“ft”) TVT 与上 Schrader Bluff 和 Prince Creek 地层的钻探前估计的 300 英尺 TVT 相比，表明资源估计可能增加 15% - 50% 与基于初步体积测定的钻探前估计的 609 百万桶相比 · 计划

从 2025 年第一季度开始，每次进行 10 天的初始四次流动测试：流动测试成功后，预计资源将重新归类为或有资源 (2C)

· 下层三个额外的潜在含油区Sagavanirktok 地层（Prince Creek 地层上方）：测井和岩屑分析确定了 670 英尺 TVT 的潜在净产层，孔隙度和渗透率极佳，加上约 1,620 英尺的测量深度（“MD”），相当于 1,040 英尺 TVT，从而带来巨大的额外资源上行潜力

· 可能需要进行三次进一步的流动测试：如果进一步的记录和分析证实了这些额外的 Lower Sagavanirktok 区域，则在暂停该井作为潜在的未来生产井/注入井之前，将对这些额外的 Lower Sagavanirktok 区域进行测试

· 所有潜在储层均被解释为含有伴生天然气的石油：基于岩屑的挥发物分析服务 (VAS) 结果表明，整个（现在估计）约 2,310 英尺 TVT 总柱中都含有液态烃，其中包含 1,340 英尺 TVT，这被解释为净产油。气体等压管分析表明石油中伴生气体。Pantheon

Resources 技术总监 Bob Rosenthal 表示：“对 Megrez-1 井结果的初步评估已经远远超出了钻探前的估计。Megrez 结构似乎捕获了一个比我们预期更大的油池。在 Prince Creek 地层上方发现的 Lower Sagavanirktok 地层中的其他潜在区域提供了我们之前未曾考虑过的进一步上行潜力。

“我们还需要开展大量进一步的工作来绘制其范围并评估最佳流量测试策略。Megrez-1 尤其令人兴奋，尤其是考虑到它的大小和位置——它实际上位于阿拉斯加输油管道下方。”

Pantheon Resources 执行主席 David Hobbs 表示：“现在对 Ahpun 油田东部常规储层进行估算还为时过早，但初步分析将钻探前预测以外的另外五个区域纳入其中，这暗示着对整个 Ahpun 油田的预期最终采收率的最佳估计可能与 Kodiak 油田的估计相媲美。

“一旦所有区域都经过测试，Megrez-1 井的商业意义将得到更好的理解，但 Bob Rosenthal 和地球科学团队对这一前景的信心已经得到充分证明。”

初步井结果确认、资源升级和测试计划

对日志、岩心和岩屑的进一步分析（使用 AHS Baker Hughes 的 VAS 服务）表明，Megrez-1 已与总共七个地平线相交，这些地平线被解释为含有液态碳氢化合物，深度约为 3,680 英尺 MD（2,310 英尺 TVT）。Megrez-1 发现的潜在油层始于 4,680 英尺 MD 或 4,514 英尺真实垂直深度（“TVD”），所有通往 8,365 英尺 MD 的 Upper Schrader Bluff TS3 底部的路。

前四次流量测试计划每次持续 10 天，将在 Upper Schrader Bluff 和 Prince Creek 地层进行。如果流量测试成功，根据岩心、测井和岩屑分析估计的储层特征、初步体积分析指向约 670 英尺 TVD 净产层（约为钻探前估计值的两倍），并将导致管理层对预期最终可采资源的最佳估计值大幅增加。钻探后估计表明，与钻探前的体积估计值相比，可能增加 15% - 50%。

成功进行流动测试后，预期 (2U) 资源将重新归类为或有资源 (2C)。公司预计，初步测试的总流量与北坡的其他 Brookian 发现相当，包括 Willow 和 Pikka/Horseshoe。

额外的预期层位

在 Upper Schrader Bluff 和 Prince Creek 地层的初始主要目标区上方的浅层中发现了额外的潜在厚层含油层，这些层位似乎是高质量的含油砂。由于这些区域的深度较浅且地震勘测参数较差，因此无法通过振幅与偏移 (AVO) 分析可靠地识别这些区域，因此很难在钻探前评估有效圈闭的可能性和资源的潜在规模。这些区域现已被分析为含有足以进行流动测试的含油饱和度。Prince

Creek 上方的这些额外含油区表现出高孔隙度和渗透率，总测量深度约为 1,620 英尺（1,155 英尺 TVD）。初步估计，这些下萨加瓦尼克托克层位的净产油量将达到 670 英尺的垂深，如果得到确认，将需要进行另外三次流量测试，之后才能将该井作为潜在的未来生产井/注水井暂停使用。

进一步分析测井岩心和岩屑的结果以及这三个额外层的体积估计值和任何流量测试结果将在可用时共享。

根据 AIM 规则 - 矿业和石油与天然气公司说明 - 2009 年 6 月，本公告中包含的信息已由合格石油工程师、石油工程师协会成员 David Hobbs 审核并签署，他在该领域拥有 40 年的相关经验。

Pantheon Resources plc (AIM:PANR, OTCQX: PTHRF) ("Pantheon" or the "Company"), an oil and gas company developing the Kodiak and Ahpun oil fields in close proximity to pipeline and transportation infrastructure on Alaska's North Slope, will be presenting at the Sequire Investor Summit today. The Company will be outlining results of log, core and cuttings analysis from the Megrez-1 well and a consequnetal anticipated upgrade of resource for Ahpun's Eastern Topset. The Company also provides an update on its flow testing plans.

Key Points

· Increase in Total Hydrocarbon Column to 2,310ft Vertical Thickness ("TVT"): Further analysis of the logs, cores and cuttings (using AHS Baker Hughes' VAS service) indicates that Megrez-1 has intersected a larger hydrocarbon liquid column than originally identified

· Potential 15% - 50% Resource Upgrade in Four Originally Identified Oil Horizons: The impact of incorporating the increased net pay thickness to 670 feet ("ft") TVT vs 300ft TVT pre-drill estimate for Upper Schrader Bluff and Prince Creek formations indicates the potential for a 15% - 50% increase in resource estimates vs pre-drill estimates of 609 mmbbls based on preliminary volumetrics

· Initial Four Flow Tests Planned at 10 Days Each, Beginning in Q1 2025: Resources expected to be reclassified to contingent resources (2C) upon successful flow testing

· Three Additional Potential Oil Bearing Zones in the Lower Sagavanirktok Formation (Above Prince Creek Formation): Log and cuttings analysis identified 670ft TVT of potential net pay with excellent porosities and permeabilities adding c. 1,620ft measured depth ("MD"), equivalent to 1,040ft TVT resulting in substantial additional resource upside potential

· Likely Requirement for Three Further Flow Tests: These additional Lower Sagavanirktok zones will be tested, if confirmed by further logs and analysis, prior to suspension of the well as a potential future producer/injector

· All Potential Reservoirs Interpreted to Contain Oil with Associated Natural Gas: Volatiles Analysis Service ("VAS") results, based on the cuttings, indicate liquid hydrocarbons throughout the entire (now estimated) c. 2,310ft TVT gross column containing 1,340ft TVT that is interpreted as net pay. Gas isotube analysis indicates associated gas with the oil.

Bob Rosenthal, Technical Director of Pantheon Resources, said: "The preliminary assessment of the Megrez-1 well results already far exceeds pre-drill estimates. The Megrez structure appears to have trapped a larger pool than we expected. The additional prospective zones in the Lower Sagavanirktok Formation, identified above the Prince Creek Formation, provide further upside that we had not previously considered.

"We will require extensive further work to map their extent and assess the best flow testing strategy. Megrez-1 is particularly exciting, especially considering its size and location - being virtually under the Trans Alaska Pipeline."

David Hobbs, Executive Chairman of Pantheon Resources, said: "It is very early to put estimates on the Ahpun Field's eastern conventional reservoir accumulations but preliminary analysis to include the additional five zones beyond the pre-drill prognosis hints at a best estimate of expected ultimate recoveries for the entire Ahpun field that may compete with Kodiak field estimates.

"The commercial significance of the Megrez-1 well will be better understood once all the zones are tested but the belief shown by Bob Rosenthal and the Geoscience team in this prospect has been fully vindicated."

Confirmation of Initial Well Results, Resource Upgrade and Testing Program

Further analysis of the logs, cores and cuttings (using AHS Baker Hughes' VAS service) indicates that Megrez-1 has intersected a total of seven horizons interpreted as containing liquid hydrocarbons over some 3,680ft MD (2,310ft TVT). Megrez-1 encountered potential oil pay beginning at 4,680ft MD or 4,514ft true vertical depth ("TVD") all the way to the bottom of the Upper Schrader Bluff TS3 at 8,365ft MD.

The first four flow tests, planned for 10 days each, will be conducted in the Upper Schrader Bluff and Prince Creek formations. In the event of successful flow tests, the reservoir characteristics estimated from cores, logs and cuttings analysis, preliminary volumetric analysis points to c. 670ft TVD net pay (approximately double pre-drill estimates) and would lead to a significant increase in management best estimates of expected ultimate recoverable resources. Post-drill estimates point to the potential of a 15% - 50% increase from pre-drill volumetric estimates.

Prospective (2U) resources would be reclassified as contingent resources (2C) upon successful flow testing. The Company expects aggregate flow rates from the initial tests comparable to other Brookian discoveries on the North Slope, including Willow and Pikka/Horseshoe.

Additional Prospective Horizons

Additional potential thick oil bearing horizons have been identified in the shallow section above the initial major target zones of the Upper Schrader Bluff and Prince Creek formations which appear to be high quality oil bearing sands. These zones could not be reliably identified on Amplitude versus Offset ("AVO") analysis due to their shallower depth and seismic survey parameters hence the likelihood of a valid trap and potential size of the resource was difficult to assess pre-drill. These zones have now been analysed as containing oil saturations sufficient to merit flow testing.

These additional oil bearing zones above the Prince Creek exhibit high porosities and permeabilities that total c. 1,620ft of measured depth (1,155ft TVD). Preliminary estimates of net pay in these Lower Sagavanirktok horizons amount to a further vertical 670 ft TVD and, if confirmed will result in a further three flow tests prior to suspension of the well as a potential future producer/injector.

The results of further analyses of the logs cores and cuttings, along with volumetric estimates for these three additional horizons and any flow testing results will be shared when available.

In accordance with the AIM Rules - Note for Mining and Oil & Gas Companies - June 2009, the information contained in this announcement has been reviewed and signed off by David Hobbs, a qualified Petroleum Engineer and a member of the Society of Petroleum Engineers, who has 40 years' relevant experience within the sector.