Thanks, operational Ian. XXXX perspective. despite expectations. initial But everyone. dramatically an year morning, our producers, changes, other plan And and was it operating good solid a Like our from from capital changed the all
suspended which the D&C achieved our significant capital we in in we started into execution and by drilling improvements. translated for cycle our and had completion activity efficiency performance times, strong of Our April, company record time terms
XX in in for average previously year-over-year. $X.X XXXX, costs to million, As wells, we we per last with well were improvement reduce efficiency, well per $X.X fourth were quarter, the our reinitiated day. to our completion a upon drilled On total pad we some which represents Bakken million further our improve completing the stages capital a able in averaging able activity to
the layer in closes. XXXX, that assumes we’ve momentum into going that to keep uncompleted Bruin well more and completions outlined Bruin���s we performance. this to this plan cost program continue our operational the this well inventory into we believe acquisition budget guidance provide But forma improve drilled XX net we year. can to We pro expect Turning detailed once
of starting reinitiate in spring Dakota to they’re plan March We activity are track X start on the and commence completion also activity to rig. at drilling in the with North
low were last summer to require which of economics, overs. And accelerating oil of providing pricing wells we wells, are Another focused will be went Bruin’s down Many the production environment over restoring simply a course. normal work area these from we price production. return robust during or current in their work the in on is with subset shut
As Berthold XXX locations and Fort Ian about we have Williams’ acreage. net drilling noted, across identified Bruin’s
about the acreage. we number, As upside to to think Williams’ relates primarily this it
Three the with locations identified For focused are Williams we’ve of only the context, Bakken envisioned their middle of focused also less or in on one-third locations about These predominantly position eastern land Williams’ portion acreage. development the Forks. their are
move system further and you their County, west as wells aren’t Williams degrades As the productive. in hydrocarbon
costs maintain the than more our likely year while due reservation. support for frac for lower in when continued we’ll partner, us momentum I Berthold, drive doesn’t our supported prices, to by keep that synergies, the time and structures Williams we’d it bring a also drilling comments costs, acreage operating, rig well inventory. lower. the acquisition increase laying to the shallower note revisit on with been be development. there the that help scale, given reducing a also higher costs operating more drilling nature plans wells it offer off our will So Ian’s down forward we’ll Fort land our production ancillary today, the than But potentially does efficient Bruin could Further including we’re dramatically commodity cost would the that reservoir allowing plan. later of Rather or to in lower Western and acreage on we not have capital if Williams’ success, and potential
operating We we to on out to the make we progress. as also operations. expect And benefits combined see these costs for report will
reserves. year-end our to Turning
our capital XXXX of levels Notwithstanding track. this, year activity reduced significant the With saw not on was where performance overall was we reserve additions. a
price proved economic due Excluding plus of probable basis. Dakota XX% we to revisions corporately a forecast, XXX% of the and replaced North on in production reduced production
were supported our by had we’ve quite numbers F&D strong Our success the costs. well reducing
BOE. BOE leave F&D F&D proved me, excuse and was was XXX BOE call proved probable Our it and per to $X.XX CAD Jodi. per the per CAD X.X there – I’ll pass plus
