非洲是一块以其丰富的自然资源而闻名的土地 ” 有多少非洲国家是世界上最大的石油生产国就证明了这一点 。在西非地区，尼日利亚和安哥拉等国家是非洲大陆石油生产的堡垒。但随着西非新能源企业的出现，竞争环境似乎正在变得公平。

“当我们审视未来五年内预计发生的活动时，它更像是 全新 一天，就像西非的日出，”Mark Adeosun，西半球 哦 离岸 米 韦斯特伍德的经理说。“未来几年，我们预计对天然气的需求将推动西非的海上油田开发，特别是毛里塔尼亚和塞内加尔的海上油田开发。 血压 “横跨塞内加尔和毛里塔尼亚的Tortue项目将推动未来大量投资，以及ENI对其刚果共和国近海Marine XII区块的投资。”

“当我们审视未来五年预计将发生的活动时，这更像是全新的一天，就像西非的日出 。 马克·阿德森，韦斯特伍德

西非近海的工程、采购和施工（EPC）机会逐渐远离传统的西非盆地尼日利亚、安哥拉和加纳，转向毛里塔尼亚、塞内加尔、科特迪瓦和纳米比亚近海的新视野。由于多种原因，较传统盆地的生产已开始放缓。

老牌强者更加成熟。尤其是尼日利亚，安全担忧和政治不确定性是部分产量放缓的原因之一。Adeosun 表示，过去 10 年，该国产量急剧下降，从 2012 年的 2 MMbbl/d 下降到 2022 年的 1.3 MMbbl/d 左右。这种下降为其他希望涉足石油和天然气领域的国家打开了大门。

“其中一些国家对石油和天然气行业相对较新，并且非常热衷于国际勘探与生产Adeosun 表示，公司将投资该国并在其海上边界内勘探碳氢化合物，以便从其石油和天然气资源中受益并帮助促进其经济发展。

Adeosun 表示，西非海上活动的增加让人想起 2012 年至 2014 年期间该地区投资热潮的情景

在毛里塔尼亚， 血压 表示 Tortue 开发的下一阶段将是他们最初预期的两倍，容量从 2.5 每年百万吨 (mtpa) 至 5 百万吨PA 。

随着大多数行业恢复到大流行前的状态，项目延误等潜在问题开始出现，就像西非普遍经历的那样。无论潜在的延误如何，只要油价继续保持在 70 美元/桶以上（与价格预测一致），项目预计就会推进。Adeosun 表示，与前五年相比，预计 2022 年至 2026 年期间受到制裁的海底树木数量可能会增加 150%。

“目前，推动EPC支出的是勘探与生产的愿望开发最多产的油藏以满足不断增长的石油需求 和 天然气，”Adeosun 说。“要做到这一点，他们需要把重点放在储量较大的地区和地区，西非大多数深水油气藏就是这种情况。”

主要国际石油公司利用了非洲的 EPC 机会，包括顶级运营商的活动，例如  血压 、埃尼集团、TotalEnergies 和壳牌。      

血压 和埃尼已组成50 : 安哥拉 50 家合资企业名为 Azule Energy , 该公司目前正准备开发此前由埃尼集团运营的 Agogo 油田。Azule 还负责安哥拉海上 10 口 Palas-Astraea-Juno 项目，该项目之前由 血压 。该深水项目正处于设计阶段，深度为 5,255 英尺 。

在纳米比亚，道达尔和壳牌正在评估新发现的储量。尽管尼日利亚是一个更成熟的盆地，雪佛龙和埃克森美孚美孚在该地区仍然非常活跃 , 与雪佛龙一起经营阿格巴米油田和埃克森美孚美孚参与二哈深水开发并在该地区拥有一些石油开采许可证。

“我认为总体而言，由于一些运营商的计划，以及当时被认为未开发的地区的其他开发潜力，我们将看到西非市场未来非常活跃，”Adeosun说。“这或多或少是西非供应链未来三到五年的梦想，与我们在巴西看到的非常相似，如果石油价格上涨，未来几年可能会批准大型项目价格保持在 70 美元/桶以上，运营商继续实施当前的开发计划。”

Africa is a land known for its abundance of natural resources— as evidenced by how many African nations comprise the top oil producers in the world. In the West African region, countries such as Nigeria and Angola are bastions for the continent's oil production. But the playing field seems to be leveling as new energy players emerge in West Africa.

“When we look at activities that we expect to happen over the next five years, it's more like a brand-new day, like a sunrise in West Africa,” Mark Adeosun, Western Hemisphere offshore manager at Westwood, said. “Over the next few years, we anticipate that the need for gas will drive offshore field development in West Africa, especially offshore Mauritania and Senegal. BP’s Tortue project, which straddles Senegal and Mauritania, will drive a lot of investment going forward, as well as ENI’s investment in its Marine XII Block offshore the Republic of Congo.”

“When we look at activities that we expect to happen over the next five years, it's more like a brand new day, like a sunrise in West Africa.” Mark Adeosun, Westwood

Engineering, procurement and construction (EPC) opportunities offshore of West Africa have gradually been trending away from the traditional West African basins of Nigeria, Angola and Ghana and moving toward new horizons in offshore Mauritania, Senegal, Ivory Coast and Namibia. Production in the more traditional basins have begun to slow down due to a myriad of reasons.

The older powerhouses are more mature. With Nigeria in particular, security concerns and political uncertainties have played a part in slowing some of the production. The country has faced a steep production decline over the last 10 years, going from producing over 2 MMbbl/d in 2012 to around 1.3 MMbbl/d in 2022, according to Adeosun. This decline has opened the door for other nations looking to throw their hat in the oil and gas ring.

“Some of these countries are relatively new to the oil and gas industry and are quite keen for international E&P companies to bring investment into the country and explore the hydrocarbons within their maritime boundaries so as to benefit from their oil and gas resources and help boost their economy,” Adeosun said.

The increase in activity offshore of West Africa evokes images of the 2012 to 2014 period when the region saw a boom in investments, Adeosun said

In Mauritania, BP indicated that the next phase in the Tortue development will now double what they originally anticipated, with capacity going from 2.5 million tonnes per annum (mtpa) to 5 mtpa.

With a majority of the industry returning to pre-pandemic form, potential issues such as project delays begin to happen, as West Africa generally experiences those. Regardless of potential delays, projects are expected to move forward as long as oil prices continue to hold over $70/bbl, in ine with price forecasts. The number of subsea trees expected to be sanctioned could increase by a 150% increase between 2022 and 2026 compared to the preceding five-year period, Adeosun said.

“At the moment, what is driving EPC spending is the desire of E&Ps to develop their most prolific reservoir to meet the growing demand for oil and gas,” Adeosun said. “To do that, they need to concentrate on areas and regions where the reservoirs are large, which is the case with most deepwater hydrocarbon reservoirs in West Africa.”

Major IOCs have taken advantage of the EPC opportunities in Africa,  including activity by top operators such as BP, Eni, TotalEnergies and Shell.      

BP and Eni have formed a 50:50 joint venture in Angola called Azule Energy, which is now poised to develop the Agogo Field, previously operated by Eni. Azule is also over the 10-well Palas-Astraea-Juno project offshore Angola, which was previously operated by BP. That deepwater project, which is in its design phase, has a depth of 5,255 ft.

In Namibia, Total and Shell are appraising newly discovered reserves. Despite Nigeria being a more mature basin, Chevron and ExxonMobil are still very active in the area, with Chevron operating the Agbami Oilfield and ExxonMobil involved with the Erha deepwater developments and owning a few oil mining licenses in the region.

“I think overall we’ll see a very buoyant market in West Africa going forward due to some of the operator plans, as well as the potential for other developments from places that were considered to be undeveloped over that time period,” Adeosun said. “It’s more or less a dream for the supply chain in West Africa over the next three to five years, very similar to what we’re seeing in Brazil, where massive projects could be sanctioned over the next few years should oil prices hold above $70/bbl and operators proceed with their current development plans.”