Africa (Sub-Sahara) A drillstem test was performed on the Zafarani-2 well--located about 80 km offshore southern Tanzania. Two separate intervals were tested, and the well flowed at a maximum of 66 MMscf/D of gas. Statoil (65%) is the operator, on behalf of Tanzania Petroleum Development Corporation, with partner ExxonMobil Exploration and Production Tanzania (35%). The FA-1 well--located in 600 m of water in the Foum Assaka license area offshore Morocco--was spudded. The well targets Eagle prospect Lower Cretaceous resources. Target depth is 4000 m. Kosmos Energy (29.9%) is the operator, with partners BP (26.4%),
Africa (Sub-Sahara) Bowleven's Moambe exploration well on the Bomono Permit onshore Cameroon has encountered hydrocarbons. The well was drilled to a planned total depth of 5,803 ft and made its discovery in Paleocene-aged (Tertiary) target reservoir intervals. Moambe is the second in a two-well exploration program on the permit. The first well, Zingana, also discovered hydrocarbons. The Moambe well will be tested before further testing takes place at Zingana. Bowleven holds 100% interest in the permit. Shell Nigeria Exploration and Production has begun production at the Bonga Phase 3 project, an expansion of the deepwater Bonga project in Nigeria. Peak production from the expansion is expected to be 50,000 BOEPD, which will be shipped by pipelines to the Bonga floating production, storage, and offloading facility.
Africa (Sub-Sahara) The drillship Ocean Rig Athena is preparing to drill appraisal and exploration wells offshore Senegal for a joint venture (JV) led by Cairn Energy. Two wells will appraise the SNE discovery, which was ranked by IHS CERA as the world's largest for oil last year. An exploration well will also be drilled in the Bellatrix prospect, for which mapping has indicated a potential 168 million bbl of oil resources. Cairn holds a 40% interest in the JV, with remaining interests held by ConocoPhillips (35%), FAR (15%), and Petrosen (10%). The Ksiri West-A exploration well drilled by Circle Oil on the Sebou permit onshore Morocco has flowed gas at a rate of 8 MMcf/D following tests. It is being readied for production.
Africa (Sub-Sahara) Eni started production from the West Hub development project's Mpungi field in Block 15/06 offshore Angola. The startup follows the project's first oil from the Sangos field in November 2014 and the Cinguvu field last April. Mpungi will ramp up West Hub oil production to 100,000 B/D in the first quarter from a previous level of 60,000 B/D. The project also includes the future development of the Mpungi North, Ochigufu, and Vandumbu fields. Eni is the block operator with a 36.84% stake. Sonangol (36.84%) and SSI Fifteen (26.32%) hold the other stakes.
Africa (Sub-Sahara) Marathon Oil has produced first gas from its Alba B3 compression platform offshore Equatorial Guinea. The startup enables the company to convert approximately 130 million BOE of proved undeveloped reserves, which more than doubles its remaining proved developed reserve base in the country. Marathon holds an operating interest of about 65% in the field, with Noble Energy holding the remaining stake. Aminex said that gas production from the Kiliwani North-1 well in Tanzania has reached 30 MMcf/D (about 5,000 BOE/D). The project's commissioning process is expected to conclude with a well test to determine the optimal production rate, which previous test data suggest will be approximately 30 MMcf/D, the company said. The operator of the Kiliwani North Development License, Aminex holds a 54.575% interest in the well.
Africa (Sub-Sahara) Tullow Oil announced in mid-August that first oil has flowed from the Tweneboa, Enyenra, and Ntomme (TEN) fields offshore Ghana, which was on time and on budget for the project's development plan approved by the government in May 2013. The company expects oil output to ramp up gradually through the rest of the year toward a production facility capacity of 80,000 B/D. Tullow is the operator of the TEN fields with a 47.18% stake. Its joint-venture partners are Anadarko (17%), Kosmos Energy (17%), Ghana National Petroleum Corporation (15%), and PetroSA (3.82%). Asia Pacific Rosneft has made a discovery at the PLDD well in the Wild Orchid gas condensate field in Block 06.1 of the Nam Con Son Basin offshore Vietnam. The discovery is being evaluated for the volume of reserves and commercial attractiveness, and there is a potential synergy with the nearby Rosneft-operated Lan Tay production platform, the company said.
Africa (Sub-Sahara) Shell has initiated a two-well drilling program in blocks 1 and 4 of the Mafia Deep basin offshore Tanzania. Drilling is taking place in water depths of up to 7,545 ft, with the company and its joint-venture partners Pavilion Energy and Ophir Energy investing almost USD 80 million in the program. The two wells will meet the remaining requirements in the exploration licenses issued by the Tanzanian Ministry of Energy and Minerals. Asia Pacific Petronas has begun gas production from the world's first floating liquefied natural gas (FLNG) facility, the PFLNG SATU, at the Kanowit field offshore Malaysia's Sarawak state. The first-gas milestone marked the onset of commissioning and startup for the FLNG facility, preceding commercial production and initial cargo shipment. The facility is fitted with an external turret for operating in water depths of 229 ft to 656 ft. It will extract gas through a flexible subsea pipeline for the liquefaction, production, storage, and offloading of LNG at the field.
You have access to this full article to experience the outstanding content available to SPE members and JPT subscribers. To ensure continued access to JPT's content, please Sign In, JOIN SPE, or Subscribe to JPT For the average oil and gas technical professional who spends hours each day scrutinizing the details, it is easy to forget the big picture. Solving the latest engineering problem comes first. Then comes solving the next one. And the problems are unique to each person and their job function.
Bari, Abdul (Schlumberger Seaco Inc.) | Dar, Usman (Schlumberger Seaco Inc.) | Zubair, Talha (Schlumberger Seaco Inc.) | Sarili, Mahmut (Schlumberger Seaco Inc.) | Siddiqi, Sarmad S. (Pakistan Petroleum Limited) | Hammad, Muhammad (Pakistan Petroleum Limited) | Jalil, Talha (Pakistan Petroleum Limited) | Siddiqui, Suhail Ahmed (Pakistan Petroleum Limited)
Over the years, wireline formation testers have been frequently used for evaluation of near wellbore reservoir characteristics using mini-DST technique. Its primary applications are especially in case of tight or laminated layers where conventional testing approach is time consumingin terms of rig time and associated cost. Such evaluation helps client in optimizing their completion strategies. One such successful application of mini DST technique has been in Kandhkot field; which is sub divided into three domes having three reservoirs Sui Main Limestone (SML), Sui Upper Limestone (SUL) and Habib Rahi Limestone (HRL). Formation evaluation which included core analysis and open hole logs; was carried out in surrounding wells encountering SUL and it showed relatively less porosity and permeability in West dome (Ф=8-12% and K=0.1–1.68mD). Testing on two wells confirmed gas presence but its potential could not be established due to low rates. To address this challenge, wireline formation testing technique with straddle packers was opted in a well KDT X, encountering SUL formation. By successful utilization of Mini DST, Operator managed to evaluate critical reservoir parameters for characterization of all individual layers, which helped in better reserves estimates and reservoir modeling.
Wireline formation testing has been in use for several decades now. Advancements in wireline formation testers have led to an effective reservoir evaluation through its various answer products. Reliable pressure and mobility measurements, fluid gradients and contacts, downhole fluid analysis and PVT sampling, vertical interference testing and reservoir characterization are few to count.
Complex lithology, naturally fractured carbonates, multiple reservoir sections and various reservoir heterogeneities present significant challenges for formation evaluation. Generally, it takes several days to weeks to test multiple formations separately; which can lead to increase in associated cost. One of the efficient approaches in such situations is to utilize wireline formation tester tools which can provide an opportunity to test multiple formations during same run. For downhole testing of laminated, tight or fractured formations, a straddle packer (commonly known as dual packer module) is used to isolate the interval of interest; followed by series of controlled drawdowns and buildups to perform pressure transient analysis, known as Interval Pressure Transient Testing (IPTT).
Mari Gas Field; discovered in 1957, is one of the oldest and mature fields of Pakistan and currently the highest gas producing field of the country. Mari Field has vital role in ensuring the food security of Pakistan as it is meeting gas needs of 87% of Fertilizer Industry. Field has been developed in multiple phases with 97 producing wells and complex gas gathering network of 284 km. In recent past few years, the country's supply and demand gap for gas is on widening trend. In order to support national energy needs, MPCL management decided to take initiative of executing gas incremental and optimization drive for playing its part in meeting the crucial energy demand of country. Furtermore, it was also matter of great importance to sustain the enhanced production plateau and meeting production & revenue targets.
Multidisciplinary teams were formed for evaluation of complete system from Reservoir to delivery end. Integrated approach was adopted for assessment of system at existing state of production and targeted production rate as de-coupled models would have not served the purpose well in this particular case. This study covers the integration of sub-surface and surface facilities; linking reservoir simulator at IPR Level, through in-house simulation model developed in commercial simulator. Keeping in view the target of study i.e. incremental and sustained production, reservoir rates were constrained and hence semi-implicit approach was used instead of fully implicit modeling which saved a lot of computation time and avoided complexities. Coupled model was simulated for predicting futuristic behavior of system at enhanced production which identified bottlenecks and integrity problems in existing system and also proposed the solutions through series of sensitivities analysis. This exercise triggered the proactive approach for solving system issues and kicked-off proper surveillance of system which are mandatory to sustain the desired production plateau and ensure the mechanical integrity of system. This study further emphasized that evaluation of complete system through integrated modeling can save compression cost at by de-bottlenecking the existing infrastructure.
At present, the field is producing at 20% incremental volume over and above of initial base volume and future plans have also been formulated to sustain the production plateau as per reservoir simulator.