|
Prudhoe Bay owners detail gas activities
Kristen Nelson Petroleum News
As part of the annual plan of development for the initial participating areas at Prudhoe Bay, field operator BP Exploration (Alaska) summarized activities related to a major gas sale, including evaluating subsurface studies of how the maximum amount of natural gas could be provided through Prudhoe Bay unit facilities.
In addition to IPA work, BP has evaluated production from Point McIntyre and Lisburne as part of the strategy to optimize the natural gas opportunity and use of the Point McIntyre field for by-product injection after gas has been recovered.
Other projects, while not directly major gas sale related, would have an impact on that project, such as upgrades and maintenance “to improve the dew point of dehydrated gas from flow stations and gathering centers,” which BP said would improve reliability of the central gas facility, benefiting oil production and potential major gas sales.
IPA work Major gas sales work at the initial participating areas includes: producing more higher Btu specification gas from the CGF through use of existing miscible injectant; use of L and V pads for by-product injection; further refinement of injection opportunities for by-product use; and evaluating potential impact of an extended outage of the trans-Alaska oil pipeline on delivery of gas to the gas treatment plant.
Surface studies related to a major gas sale include working with the Alaska LNG project to confirm feasibility of by-product from Prudhoe to the GTP flares in the event of an operational upset; CGF tie-in philosophy and facility maintenance turnaround strategy, with a sales gas tie-in designed from the existing CGF to the GTP tie-in; providing greater operational flexibility; reducing requirement for maintenance turnaround during construction; and reducing overall cost from the initial design.
Requests for information BP said it has been responding to requests for information from parties interested in large ANS gas development projects for years, most recently from AKLNG. During 2016 information requested included: review and analysis of AKLNG’s GTP air permitting modeling; review and analysis of AKLNG’s documents on the interface between the GTP and Prudhoe Bay unit facilities; confirmation that sales gas could be sent to the GTP tie-in point at 720 psig versus the existing sales gas system design pressure of 790 psig; confirmation of feasibility of flowing by-product from Prudhoe to the GTP flares; design of a sales gas tie-in from the CGF to the GTP that provides greater operational flexibility, reduces the requirement for a maintenance turnaround during construction and reduces overall cost of the initial design; review and analysis of AKLNG’s draft Federal Energy Regulatory Commission resource reports by subject matter experts; response to requests for detailed CGF documentation; and review and analysis of AKLNG’s GTP infrastructure needs and potential impacts to the Prudhoe Bay unit.
“As appropriate, activities will be undertaken during 2017-18 plan period to prepare for a MGS,” BP said, adding that it plans to respond to requests for information from the Alaska Gasline Development Corp. related to AKLNG.
BP said AGDC is considering options including phased development, and when AGDC issues a timeline for major project milestones, “the unit owners anticipate undertaking appropriate activities to position for an MGS consistent with AGDC’s progress.”
BP also listed activities to optimize use of gas before a major gas sale by producing oil by injection of lean gas and miscible injection into Prudhoe Bay reservoirs, noting that the use of gas injection contributes some 40 percent of Prudhoe oil production through vaporization and enhanced oil recovery with miscible injectant.
“The use of gas is a valuable opportunity in the near-term and current activities will continue to pursue production through the use of processed gas,” BP said.
| 