Jul 2021: BP, along with PTTEP, Petronas and Qatar’s energy ministry increased production of unconventional gas from Block 61 for use at Oman LNG. Gas production increased to around 15 bcm a year. Gas from Block 61 is also distributed for domestic consumption and as fuel for power plants.
Apr 2021: Masirah Oil (100%) has drilled 3 exploration wells near the Yumna field in Block 50. Zakhera encountered oil shows, while Yumna East and Yumna North were dry holes. The wells were drilled for US$3.5 mm each. Meanwhile Masirah upgraded capacity of its production facilities to 30,000 bbls per day to handle production from 3 Yumna production wells.
Feb 2021: Masirah announced that production has commenced from the 3rd development well in the offshore Yumna field in Block 50. The well was tested at 12,984 bbls of oil per day from the Lower Aruma sandstone.
Jan 2021: Masirah announced production from the 2nd development well in the Yumna field, offshore Block 50. A 3rd production well, Yumna-3, has been spudded targeting a crestal location in the field. The production facilities at the Yumna MOPU are being upgraded to double the liquid processing capacity.
Nov 2020: Masirah Oil has contracted Shelf Drilling’s jackup Tenacious for 2 development wells on the Yumna oil field and one exploration well in block 50 from December.
Oct 2020: BP (60%), Makarim - OQ (30%), Petronas (10%) and the Ministry of Energy & Minerals announced production has begun from Phase 2 of Block 61 (the Ghazeer tight gas field). The 1st phase (Khazzan) was brought online in 2017. Production capacity from Khazzan and Ghazeer is expected to rise to 15 bcm of gas a year and 65,000 bbls per day of condensate.
Jul 2020: The Ministry of Oil and Gas approved Masirah Oil’s development plan for the offshore Yumna oil field in block 50. An early production test is currently producing over 8,000 bbls of oil per day from Yumna-1. A mobile offshore production unit (MOPU) is installed along with a storage tanker. An appraisal well will be drilled in 2021.
Jun 2020: BP plans to produce an additional 2.5 Bcm of gas from the Khazzan tight gas field (Ghazir) by the end of 2020, lifting output to around 12 Bcm for the year in addition to 35,000 bbls per day of condensate. A total of 126 (out of 300) wells have been drilled.
Feb 2020: Masirah Oil has completed the Yumna 1 well in Block 50 and flowed first oil into an Aframax tanker for its early production test.
Feb 2020: Eni (operator, 55%), with Qatar Petroleum (30%) and Oman Oil (15%), has commenced drilling the first deep water well in Oman with the Pacifica Bora drillship in Block 52.
Jan 2020: Masirah Oil has raised funds to drill the Yumna field offshore appraisal well in Block 50. Rex Oman holds 86.37% of Masirah, with Schroders (7.03%), Trace Atlantic (4.66%), Petroci (1.83%), and Masirah management (0.10%). An FSO will used from January 2020 on the Yumna field (formerly GA South) to store oil from an early production test .
Jul 2019: PDO started-up the Rabab Harweel Integrated Project (RHIP) with gas production from six wells in the Harweel cluster of fields in the Southern desert. It includes sour gas processing, gathering and injection systems, and export pipelines. Sweet gas is to be exported through the Salalah Gas Pipeline (SGL) and condensate to the Main Oil Line (MOL) via Marmul.
Apr 2018: Total (100%) has been awarded an exploration license (Block 12) following agreement on an integrated gas project of the Greater Barik area in Blocks 10 and 11. Block 12 lies onshore to the south of the Greater Barik area. Drilling will begin in 2020.
Jan 2019: DNO has relinquished offshore Block 8 to state-owned Oman Oil Company Exploration and Production (OOCEP). It contains the Bukha and West Bukha fields. Musandam Oil and Gas, owned by OOCEP, will take over as operator.
May 2018: Total (25%), with Shell (operator, 75%), signed an MOU to develop natural gas resources in Oman in the Greater Barik area on onshore Block 6 with the objective of a plateau gas production of 10 bcm per year. Total will use its gas as feedstock for an LNG plant and bunkering service to marine vessels in Sohar port.
Apr 2018: BP (operator, 60%) and Oman Oil (40%) approved development of Ghazeer in Block 61, the second phase of the Khazzan tight gas field. The first phase started in 2017 and is producing around 10 bcm of gas per year and 35,000 bbls per day of condensate. Ghazeer is expected to come onstream in 2021 and deliver 5 bcm a year and 15,000 bbls of condensate per day.
Mar 2018: Petroleum Development Oman (PDO) confirmed discovery of the Mabrouk North East gas field (Barik and Miqrat reservoirs) in the northern part of its concession area, 40km west of Saih Rawl. Five wells have now been drilled, all have encountered gas, and one is already producing. In 2013 PDO announced the nearby Mabrouk Deep discovery.
Dec 2016: BP (operator) announced that production has begun from Phase One of the Khazzan gas field in Block 61. The PSA was signed in 2007, was amended in 2013 and extended in 2016. Phase One is made up of 200 wells feeding into a two-train central processing facility and is expected to plateau at 10 bcm of gas a year with the second phase increasing this to 15 bcm.
Dec 2016: The Ministry of Oil & Gas has included 4 four blocks in the Oman Bid Round 2016 (Blocks 30, 31, 49, and 52). Block 52 (Juzor Al Hallaniyyat) is the only offshore block.
Nov 2016: BP (operator, 60%) and Oman Oil (40%) signed a deal with the government to amend the Block 61 PSA Khazzan gas field area to the south and west of the original 2,700 square kms.
Oct 2016: The first phase of the Khazzan tight gas project operated by BP (60%), 350 kms south of Muscat, is 80% complete and on track to deliver first gas near the end of 2017. Equipment installation is now in progress for the 2-train gas processing facility whilst 38 of the 50 wells needed by first gas are already drilled with more than 300 planned. Oman Oil holds the remaining 40%.
Jun 2016: The Ministry of Oil and Gas plans to start tendering around 5 oil blocks around the country in October this year on a production sharing basis.
Feb 2016: BP (operator, 60%) and Oman Oil (40%) signed a deal to develop a second phase of the Khazzan gas field. The cost of the entire project is US$16 bn. Khazzan in Block 61 is a large tight gas accumulation with plateau production from both phases expected to be 16 bcm each year.
Nov 2015: DNO (operator) reported production from the Bukha and West Bukha offshore fields in Block 8 averaged 7,323 bblsoe per day during the third quarter of 2015. The company may drill an additional development well to raise output at West Bukha.
Sep 2015: Gardline CGG will carry out surveys to determine the limits of the Omani continental shelf. The 3 phases will include 2D seismic with bathymetry, gravity and magnetic data; bathymetry and sub-bottom profiling; and deep water rock dredging.
Sep 2015: Oman has reduced its LNG exports in 2015 due to rising demand and a shortage of indigenous gas. The Khazzan gas project, due to start up in 2017, and eventual piped gas from Iran will help to offset declining exports.
Apr 2015: Total has pulled out of deep water Block 41 after failing to make commercial discoveries. The company signed a PSA in December 2013 for the block in water depths up to 3,000m. In 2014 MOL pulled out from Block 34 and DNO from Block 31.
Feb 2015: - Oman is boosting oil output as much as possible with oil and gas accounting for 79% of revenue. It has no plans to join OPEC. There will also be some cost reduction but no activity reduction. The government is also in talks with Iran to build a gas pipeline to transport gas from the South Pars field to Oman. Gas demand in Oman is growing at up to 10% each year.
Aug 2014: The government has invited bids for 5 exploration blocks in its Oman Bid Round 2014. Two of the blocks are offshore (Blocks 18 and 59) and 3 onshore (Blocks 43A, 54 and 58). The deadline for the submission of bids is end October 2014.
Mar 2014: Petrofac has won a 4.5 year engineering and procurement contract worth US$1 bn from PDO for work on the Rabab Harweel Integrated Project (RHIP) on the Harweel cluster including sour gas processing, gathering and injection systems and export pipelines. Production will be 1.8 bcm per year of gas and 60,000 bbls per day of condensate plus injection gas.
Mar 2014: Masirah Petroleum announced an oil find in the GAS-1 well in offshore Block 50. A flow test achieved 3,000 bbls per day with no water. GAS-1 is the first offshore oil discovery east of Oman. Masirah is a subsidiary of Lime Petroleum (64%) and Petroci (36%).
Feb 2014: Tethys Oil reports that the B4EW6 well, 13 kms south of the B4EW4 discovery in Block 4, has tested flows in excess of 2,200 bbls per day from the Lower Buah formation. The well has been hooked up to the production system for a long term production test. Tethys has 30% of Blocks 3 and 4 along with Mitsui (20%) and operator CC Energy (50%).
Jan 2014: BP expects up to 30% of Oman's gas supply will come from its Khazzan-Makarem tight gas field in Block 61 by the year 2020.
Jan 2014: Oman aims to produce oil at current levels for 3 years using IOR techniques to arrest an output decline. Oman's oil and condensate production averaged 930,000 bbls per day in 2013.
Dec 2013: BP has signed a gas sales agreement and amended PSA for the development of the Khazzan tight gas field in Block 61. The full field development will involve drilling 300 horizontal wells over 15 years to deliver plateau production of 10 Bcm of gas each year and 25,000 bbls per day of condensate by 2018. Total investment is US$16 bn. Oman Oil Company will hold 40%.
Feb 2013: DNO reports that production has declined from record rates last November in Block 8 to around 17,000 bbls per day of oil and condensate and 0.51 bcm per year of gas. Drilling of the third and final development well in the current campaign is expected to be completed in March and further drilling or well stimulation on the West Bukha field is being considered.
Nov 2012: DNO announced that offshore Block 8 has climbed to 20,000 bbls per day of oil and condensate along with 0.6 Bcm per year of gas after a 2 well drilling program in the West Bukha field. Block 8 contains Oman's only offshore fields. The rig is to be moved to begin an appraisal well in the Bukha gas-condensate field.
Nov 2012: DNO has flowed the West Bukha-4 well in Block 8 at 7,000 bbls of oil per day with gas. West Bukha-4 will be connected to the export pipeline system and is expected to nearly double current oil production from the field to 15,000 bbls per day. The longest reach well drilled offshore Oman at nearly 6,000 m is the second of 3 wells to be drilled in Block 8. DNO International holds 50% with Korea's LG holding the remaining 50%.
Sep 2012: The exploration well B4EW3 on Block 4 has been successfully completed. It flowed 2,400 bbls per day from the Khufai formation and has been connected to production facilities at the Saiwan East oilfield to undergo a long term production test. A 36m oil column was encountered in the Khufai formation. The well was drilled 6 kms east of Saiwan. The operator of Blocks 3 and 4 is CC Energy Development with 50%. Tethys has 30% and Mitsui 20%.
Sep 2012: DNO has brought back online its West Bukha field off Oman after a five-month shutdown. Production from the field in Block 8, which was halted due to a blockage in the pipeline connecting it with the nearby Bukha field, has been restarted at a rate of 10,000 bbls per day of oil and 258 bcm per year of gas. Output from the Bukha field was not affected, running as normal at 400 bbls per day of liquids and 103 bcm per year of gas.
Sep 2012: BP will invest US$24 bn for the first phase full-field development of Block 61 Khazzan and Makarem tight gas fields discovered in 1993 in north-central Oman. The first phase is spread over a 25 year period and aimed at producing 190 bcm of gas with delivery expected by 2017, eventually reaching 10 bcm per year. The second phase is envisaged to produce another 10 bcm per year. The plan is to drill and fracture 282 wells. BP signed its PSA in 2007 for Block 61.
Mar 2004: The Ministry of Oil and Gas has taken first delivery of natural gas from the Northern Oman Gas Joint Venture (NOGJV) developing the associated and non-associated gas reserves of Block 9. Occidental is operator (65%) with Mitsui (35%).
Mar 2003: Heritage reports the Tibat-1 offshore well in Block 17 is a gas/condensate discovery. Heritage holds 10% in Block 17 through subsidiary Eagle Energy. Partners are Novus (operator, 40%), LG (25%) and Atlantis (25%). It also holds 10% in Block 8 (containing the Bukha gas/condensate field).