Gulf of Guinea

Journal of Petroleum TechnologyAugust, 2022

Mystery Supertanker Awaits Fate After Equatorial Guinea Seizure

An oil supertanker that Nigeria tried to seize has been stuck off the coast of nearby Equatorial Guinea for more than 10 days, where it was impounded by local authorities. The Nigerian navy said that its counterparts in Equatorial Guinea arrested the Heroic Idun on 12 August, four days after the same vessel allegedly tried to load a cargo of crude unlawfully from the deepwater Akpo field operated by TotalEnergies. The ship lacked the necessary clearance and left Nigerian waters before being intercepted by the Equatoguinean military, the navy said on 19 August. The Nigerian navy said that the ship was on hire to trading giant Trafigura Group, but that appears to not be the case, according to a person familiar with the matter. The tanker was on lease to BP from Mercuria Group around the time the navy tried to seize it on 8 April, according to another person with knowledge of the situation.

Journal of Petroleum Technology

equatorial guinea seizure, Fate, freight & logistics services, group, heroic idun, marine transportation, nigerian navy, ship

Country:

Africa > Equatorial Guinea (0.89)
Africa > Nigeria > Gulf of Guinea > Niger Delta (0.28)

Industry:

Energy > Oil & Gas (0.97)
Transportation > Marine (0.64)
Transportation > Freight & Logistics Services > Shipping > Tanker (0.64)

Oilfield Places:

Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > OPL 246 > Akpo Field (0.99)
Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > OML 130 > Akpo Field (0.99)

Abstract The AKPO field is a condensate field that is currently in a mature phase with the attendant challenge of enhancing field life to maximize investment. To combat this challenge, targeting of un-swept oil using infill wells is implemented in the field to prolong production. We present seismic reservoir characterization, dynamic reservoir model simulation, and resistivity modeling efforts that were employed during the design and geosteering of a high angle infill well into an un-swept area of a complex channel turbidite reservoir. The geosteering was successful with net sand in the drain surpassing the pre-well prognosis. A key highlight of the success was the termination of the well 500 m short of the prognosed TD due to attainment of net sand required for well completion that was more than prognosis, thus reducing the well cost. At start-up, oil production from the well was significant, with production after ramp-up at 5000 bopd, thus validating our integrated geological, geophysical, and engineering approach.

doi: 10.2118/211962-MS

SPE Nigeria Annual International Conference and Exhibition

SPE-211962-MS

Country:

Africa > Nigeria > Niger Delta (1.00)
Africa > Nigeria > Gulf of Guinea > Niger Delta (0.25)

Geophysics:

Geophysics > Seismic Surveying > Seismic Processing (1.00)
Geophysics > Time-Lapse Surveying > Time-Lapse Seismic Surveying (0.97)
Geophysics > Seismic Surveying > Seismic Interpretation > Seismic Reservoir Characterization (0.51)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > OPL 246 > Akpo Field (0.99)
Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > OML 130 > Akpo Field (0.99)
Africa > Nigeria > Niger Delta > Niger Delta Basin (0.97)

SPE Disciplines:

Reservoir Description and Dynamics > Reservoir Simulation (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Seismic processing and interpretation (1.00)
Reservoir Description and Dynamics > Reservoir Characterization > Seismic modeling (1.00)
(4 more...)

Technology: Information Technology (0.70)

Overcoming the Late-Stage Development Challenges of Bonga Turbidite Reservoirs via Geosteering Technology Deployment

Abstract The Bonga field is in its late stage Phase-3 development. Infill wells are drilled to target oil in the bypassed or unswept areas of the reservoirs. Unlike the earlier phases of development, the current wells have complex trajectories and are hooked up via crowded subsea manifolds. Because oflimited availability of drilling centers, most of the new wells are extended reach with narrow drilling margins. The target reservoirs are relatively thinner, poorly developed, and more limited in extent and size compared to targets in the earlier phases, increasing inherent subsurface uncertainties. With an expected low case ultimate recovery per well of roughly 10–15 MMstb, and average deepwater well cost of +/- $40 million, the stakes were high and hence critical to get it right the first time. If net-sand is poor or short because of suboptimal landing or well placement in the reservoir, the well objective (recovery and rate) can easily be compromised and could require drilling a sidetrack with additional attendant cost. Longer exposure length of drain hole (reservoir section) was known to improve well production rates hence an essential component of the well plan. To address these challenges and ensure the wells achieve their objectives and deliver their economic value, a geosteering technology (Reservoir Mapping While Drilling tool—GeoSphere) was adopted for optimal landing above the target reservoir(s) and placement within the reservoir channel sands using the Multilayer Distance to Boundary technology (PeriScopeHD). The deployment of geosteering technology was considered to be a success in enabling better sand exposures of the wells in the target sections, thus achieving the well objectives. This paper discusses the implementation of geosteering technology and learnings from two case studies in the Bonga infill campaign.

doi: 10.2118/212029-MS

SPE Nigeria Annual International Conference and Exhibition

SPE-212029-MS

Country:

Europe (0.95)
North America > United States > Texas (0.69)
Africa > Nigeria > Gulf of Guinea > Niger Delta (0.25)

Genre: Research Report (0.34)

Geophysics: Geophysics > Seismic Surveying > Seismic Processing (0.36)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places: Africa > Nigeria > Gulf of Guinea > Niger Delta > Niger Delta Basin > OML 118 > Bonga Field (0.99)

SPE Disciplines:

Well Drilling > Drilling Operations > Geosteering / reservoir navigation (1.00)
Management > Asset and Portfolio Management > Field development optimization and planning (1.00)

Technology: Information Technology (0.72)

Chime, Chukwudalu Emmanuel (Waltersmith Petroman Oil Limited) | Kalio, Ibinabo Greenson (Waltersmith Petroman Oil Limited)

Selection of Optimal Sand Exclusion Methods for Wells in The Onshore Niger Delta: The Ibigwe Field Case Study

Abstract Sand production is a pertinent issue in oil and gas well engineering and a major cause of concern for the production engineer. He can plan for it, or he can prepare for it, albeit he would rather have it nipped in the bud right from the well’s completion phase. Sand production is costly, reducing the lifetime and durability of pipelines and production facilities, inadvertently impacting the company’s balance sheet negatively and in some cases reducing the life and productivity of the well itself. This paper critically evaluates sand production in the Niger Delta, using the Ibigwe field operated by Waltersmith Petroman Oil Limited as a case study. It proffers optimal sand exclusion methods for wells in the Niger Delta by analysing various subsurface datasets and historical sand production from offset wells within the field. The subsurface datasets identified as relevant to this study include sonic transit time, depth of burial of zones of interest, particle size analysis, geomechanical data (specifically unconfined compressive stress logs), Rate of Penetration (ROP) and other data logs. Evaluating all relevant data to the subject is imperative as discovered during research; none of the datasets listed above can be analysed in isolation, rather interdependently. The selection of an optimal sand exclusion method consequently affects the deployment of an effective completion mechanism and as such, this endeavour should be carried out conscientiously.

doi: 10.2118/211983-MS

SPE Nigeria Annual International Conference and Exhibition

SPE-211983-MS

Country:

Africa > Nigeria > Niger Delta (0.95)
Africa > Nigeria > Gulf of Guinea > Rivers > Niger Delta (0.64)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Africa > Nigeria > Niger Delta > Niger Delta Basin (0.99)
Africa > Nigeria > Gulf of Guinea > Rivers > Niger Delta > Niger Delta Basin > OML 16 > Ibigwe Field (0.99)

SPE Disciplines:

Well Drilling (1.00)
Well Completion > Sand Control (1.00)
Well Completion > Completion Installation and Operations (1.00)
(4 more...)

Ihekoronye, Kingsley Kelechi (Abubakar Tafawa Balewa University) | Mohammed, Hussein (Federal University of Technology Owerri) | Onuorah, Pius Chukwuebuka (University of Ibandan)

Application of Sodium Lauryl Sulfate for Enhanced Oil Recovery of Medium Crude Oil in the Niger Delta Fields

Abstract This research work focuses on the performance of sodium lauryl sulfate as surfactant in enhanced oil recovery of medium crude oil in the Niger Delta fields. Characterization of the sodium lauryl sulfate (surfactant) was carried out to determine the functional groups and morphology of the sample. Different tests such as interfacial tension reduction and adsorption test were conducted to evaluate the effectiveness of the sample in enhanced oil recovery. Core-flooding experiment was performed using the sample to determine the potency of sodium lauryl sulfate in enhanced oil recovery process. The results from this work showed that incremental oil recoveries of 47.8 %, 54.6 % and 56.1 % using Berea core sample (C1F) and 49.3 %, 57.6 % and 58.5 % for core sample (C2F) was observed. The results showed that sodium lauryl sulfate achieve macroscopic sweep displacement efficiency via interfacial tension reduction between the surfactant slugs and the trapped oil which helps to improve oil production.

doi: 10.2118/211978-MS

SPE Nigeria Annual International Conference and Exhibition

SPE-211978-MS

chemical flooding methods, enhanced oil recovery, enhanced recovery, experiment, mil, recovery, reduction, reservoir, sodium lauryl sulfate, surfactant, surfactant concentration, Surfactant Flooding, Upstream Oil & Gas, waterflooding

Country:

North America > Canada > Saskatchewan (0.71)
Asia > Middle East > Israel > Mediterranean Sea (0.71)
Africa > Nigeria > Gulf of Guinea > Niger Delta (0.71)
Africa > Nigeria > Niger Delta (0.62)

Genre: Research Report > New Finding (0.67)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (1.00)
Reservoir Description and Dynamics > Improved and Enhanced Recovery > Chemical flooding methods (1.00)

Ihekoronye, Kingsley Kelechi (Abubakar Tafawa Balewa University)

Formulation of Bio-Surfactant Augmented with Nanoparticles for Enhanced Oil Recovery

Abstract In this study, a novel concept of enhanced oil recovery was explored to improve oil recovery in the Niger Delta oil fields. Experimental investigation of bio-surfactant augmented with nanoparticles was evaluated to determine the influence of the nanoparticles on enhanced oil recovery. Bio-surfactant derived from yellow oleander seeds oil was formulated. Nanoparticles such as silicon oxide, titanium oxide, aluminum oxide and magnesium oxide was used as a displacing fluid due to its ability to alter the rock wettability (oil-wet to water-wet) and interfacial tension reduction of the oil/water interface of the rock property. Core-flooding experiment was conducted using four Berea sandstone cores sample obtained from the Niger Delta oil field to investigate the suitability of the nanoparticles and bio-surfactant in enhanced oil recovery process. The results of this study shows that nanofluid flooding with silicon oxide, titanium oxide, aluminum oxide and magnesium oxide had oil recoveries of 43.72%, 45.76%, 46.12%, and 47.07%, 42.41%, 45.00%, 47.02% and 48.10%, 46.10%, 47.31%, 50.26 % and 51.70%, 40.31%, 41.75%, 44.43% and 45.00% respectively. However, nanoparticles augmented with Bio-surfactant had oil recoveries of 46.20%, 48.08%, 52.00% and 53.31%, 45.61 %, 49.51 %, 50.87% and 51.46%, 47.26 %, 48.90%, 51.20% and 52.90%, 43.70%, 46.01%, 47.52% and 48.21% respectively at different concentrations of nanoparticles and bio-surfactant. The result from this study shows that nanoparticles with bio-surfactant improve oil recovery via interfacial tension reduction and wettability change.

doi: 10.2118/212001-MS

SPE Nigeria Annual International Conference and Exhibition

SPE-212001-MS

Country:

North America > Canada > Saskatchewan (0.54)
Asia > Middle East > Israel > Mediterranean Sea (0.54)
Africa > Nigeria > Gulf of Guinea > Niger Delta (0.54)
Africa > Nigeria > Niger Delta (0.45)

Genre: Research Report > New Finding (1.00)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Reservoir Description and Dynamics > Improved and Enhanced Recovery > Chemical flooding methods (1.00)
Reservoir Description and Dynamics > Improved and Enhanced Recovery > Waterflooding (0.97)
Well Drilling > Drilling Fluids and Materials > Drilling fluid management & disposal (0.79)

Ajani, Mofopefoluwa A. (Department of Petroleum Engineering, University of Ibadan) | Isehunwa, Sunday O. (Department of Petroleum Engineering, University of Ibadan)

Effectiveness of Mangifera Indica Peels for Heavy Metal Adsorption in the Treatment of Produced Water from Niger-Delta Oilfields

Abstract Produced water usually contains contaminants such as hydrocarbon fractions, heavy metals, corrosion inhibitors, etc. which are potentially harmful to the environment. Produced water has to be treated to conform to regulatory standards. Treatment techniques that are both robust and cost-effective need to be developed to increase the economic viability of produced water treatment. This research evaluates the effectiveness of mango peels as bio-adsorbents in the treatment of produced water and the effectiveness of modifications made to the mango peels. Produced water samples were obtained from Niger Delta and analysed for heavy metals using atomic absorption spectrophotometry (AAS). In this study, mango peels were washed with distilled water, sun-dried and oven-dried at 80°C. The adsorbent was pulverized and sieved (212 μm). Three batches of adsorbent were prepared: unmodified, 0.2 mol/L NaOH treated and 0.5 mol/L NaOH treated mango peels. Samples were treated with individual batches of adsorbent for up to six hours. Treated samples were analysed with AAS. The adsorption capacity, as well as the removal efficiency, were also determined. Adsorption was assessed using the Langmuir and Freundlich models. For the 0.2 mol/L NaOH adsorbent treatment, the removal efficiency for the metal concentrations (Ni, Pb, Fe, Mn, Cu, and Zn) were found to be 58.33%, 100.00%, 95.00%, 75.00%, 56.00% and 98.67% respectively, while the removal in 0.5 mol/L NaOH adsorbent treatment for the heavy metals were 95.83%, 100.00%, 93.00%, 90.79%, 68.00%, 97.35% respectively. The unmodified mango peels proved to be ineffective because the metallic concentration in the produced water increased after treatment (except for Lead and Copper). The modified variants proved to be effective as they reduced metallic concentration. The 0.5M NaOH modified variant outperformed the 0.2M NaOH modified variant. This shows that pH and contact time affect the adsorption process.

doi: 10.2118/212006-MS

SPE Nigeria Annual International Conference and Exhibition

SPE-212006-MS

Country:

Africa > Nigeria > Niger Delta (0.61)
North America > Canada > Saskatchewan (0.50)
Asia > Middle East > Israel > Mediterranean Sea (0.50)
Africa > Nigeria > Gulf of Guinea > Niger Delta (0.50)

Genre: Research Report > New Finding (0.34)

Industry:

Water & Waste Management > Water Management > Lifecycle > Treatment (1.00)
Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

Europe > United Kingdom > North Sea (0.89)
Europe > Norway > North Sea (0.89)
Europe > Netherlands > North Sea (0.89)
Europe > Denmark > North Sea (0.89)

SPE Disciplines: Health, Safety, Environment & Sustainability > Environment > Water use, produced water discharge and disposal (1.00)

Carbon Capture and CO2 EOR/Storage--A Game Changer CCUS Technology

The Way AheadApril, 2022

With an intent to reduce greenhouse gas emissions, oil and gas companies are exploring different ways to become carbon neutral in the next 20 to 30 years. To achieve this target, carbon capture and storage (CCS) plays a vital role, with the help of petroleum engineering and geoscience skills. Companies need to leverage existing assets and technology to establish a successful low-carbon venture technology. Table 1 shows the sources of CO2 emissions during energy production, transportation, and consumption. Anthropogenic CO2 (CO2 associated with human activities) projects were successful in the past and a few are listed in Table 2. Chevron's Gorgon CO2 injection project in Northwest Australia is one of the largest CO2 injection projects in the world.

The Way Ahead

Carbon Capture, Chevron, climate change, co2 eor, co2 eor project, co2 eor storage, Dupuy Formation, game changer ccus technology, Injection Project, Institute, low-carbon venture technology, Permian Basin, reservoir, subsurface storage, unconventional reservoir, Upstream Oil & Gas

Country:

North America > United States > Texas (0.99)
Africa > Nigeria > Gulf of Guinea > Niger Delta (0.16)

Geologic Time: Phanerozoic (0.32)

Industry: Energy > Oil & Gas > Upstream (1.00)

Oilfield Places:

North America > United States > Texas > Permian Basin > Yeso Formation (0.99)
North America > United States > Texas > Permian Basin > Yates Formation (0.99)
North America > United States > Texas > Permian Basin > Wolfcamp Formation (0.99)
(29 more...)

SPE Disciplines:

Reservoir Description and Dynamics > Storage Reservoir Engineering > CO2 capture and sequestration (1.00)
Reservoir Description and Dynamics > Improved and Enhanced Recovery (1.00)
Health, Safety, Environment & Sustainability > Environment > Climate change (1.00)

Okoro, Felix (Shell Petroleum Development Company of Nigeria Ltd.) | Arochukwu, Elias (Shell Petroleum Development Company of Nigeria Ltd.) | Adomokhai, Segun (Shell Petroleum Development Company of Nigeria Ltd.) | Dennar, Linda (Shell Petroleum Development Company of Nigeria Ltd.)

Front-End Integrated Production System Modelling for Production Optimization – Experience from a Niger Delta Field

OnePetroAugust, 2021

Abstract The M001 project involved the hook-up of 12 wells (17 conduits) which were drilled and completed between year 2000 and 2005 but were closed-in for operational reasons, until year 2019 when the first seven (7) conduits on cluster MX1 were cleaned up successfully. The seven conduits (Well-A, Well-B, Well-C, Well-D, Well-E, Well-F & Well-G) were expected to flow via three 8" bulk lines. Post well open-up and handover to production, significant bulking / backing out effects were observed. An average Flow Line Pressure (FLP) of ∼22 bar was recorded on the flowlines, hence limiting the capacity to bulk the wells, [FLP increases towards Flowing Tubing Head Pressure (FTHP) hence, pushing the well out of the critical flow envelope as FTHP<<1.7FLP]. Due to this challenge, total production from Cluster MX1 was sub-optimal with only five (5) conduits out of seven (7) able to flow due to bulking and backing out effect. The sub-optimal performance from the conduits were investigated using the Integrated Production System Model (IPSM) / PIPESIM models. Four different scenarios were run in the model and the calibrated IPSM model indicated all 7 conduits should flow if there are no surface restrictions. The model identified pressure, mass and rate imbalances in the integrated system and suggested the presence of a restriction at the manifold, causing sub-optimal production from the wells. The model outcome triggered an onsite investigation / troubleshooting from the wellhead to the manifold at the facilities end where an adjustable choke was identified in the ligaments of the manifold. In line with process safety requirements, a risk assessment was carried out and a Management of Change (MOC) raised to remove the adjustable choke at the manifold. Post implementation of the intervention, all the seven (7) conduits produced without any bulking effect. Total production realized from the seven (7) conduits post execution of the recommended action is ca. 9.3 kbopd against 5.2 kbopd pre-intervention. A total of ca. 4.1 kbopd production gain was realized and 10 mln USD proposed for additional bulkline was saved.

doi: 10.2118/207124-MS

SPE Nigeria Annual International Conference and Exhibition

SPE-207124-MS

Country:

Africa > Nigeria > Niger Delta (0.41)
North America > Canada > Saskatchewan (0.40)
Asia > Middle East > Israel > Mediterranean Sea (0.40)
Africa > Nigeria > Gulf of Guinea > Niger Delta (0.40)

Industry: Energy > Oil & Gas > Upstream (1.00)

SPE Disciplines:

Production and Well Operations > Well & Reservoir Surveillance and Monitoring > Integrated modeling (1.00)
Management > Asset and Portfolio Management > Integrated asset modeling (1.00)