Thank you, Sean.
half In production. pad on operational area, day per portfolio. cubic In in flowback, well of AWP oil XX barrels day at our was in feet yields Bracken our in on NGL the Artesia of by gas displayed recent feet after We drilled Production XX activity Evans to our drove higher-than-expected during months oil have equivalent XXX XXX two which the our a third quarter third out-performance cubic million substantial two of our production. our year. averaged first the of area, per barrels gas, higher-than-expected per results. which net across during NGL million the first increase Moving wells net versus the driven sales wells of seven to brought quarter wells
As bring wells we we year, additional and expect XX November to in an X to out the December. net close
XXX with wells gathering cubic Grande timing The guiding quarter, XXX uncertainty area million million Fasken in production and the extended range For day. per shutting our delays equivalent given is are on completion. area, Oro associated we a line our result waiting of of of for in gas feet times fourth to
the for times add wells been complexity. strength a cycle of be to of which that layer for While many ours, have additional an short pads, production will turned multiwell
three pad six wells. our well and of included area. During well quarter, Grande, Artesia in Fasken and our wells Eagle final The well the Ford Eagle six our completed two three Mas Fasken the and three well pad third areas, in Oro Fasken in Uno Lower pads Upper we a wells a pad area three also Ford
operational shift our high Fasken, completions the year. expected Uno intensity plan We wells improvements, the operate and the Grande with other and our a remainder Uno two its result areas type Mas drilling Oro their area - in above area Mas to while curves of curve. producing type AWP, Artesia producing our As all are recent is for at of rigs to
focus our Our on portfolio March and in Western added portion La of will in Southwest Eagle high-specification continue rig the Salle counties. Ford Webb early
on and Ford our The Eagle other areas. focus rig AWP Southern drilling will
of costs, continue operating and improved our use of functions. procedures unit sand equipment equipment replacement cost, As existing for facilities, completions, rental company-owned in for These we processes all and to and of evaluate with of include and procurement the initiatives optimize equipment. regional redundant elimination utilization our of
white We As current and compelling further sand wells, able Mcfe sales chemical third a renegotiating to focus using in and wells looking for $X.XX maintenance sand, of we during per a proposition, expenses labor on comparably our on reservoir. optimizing and increase to and were both XX%. quarter were of achieve for white we Northern Northern the that compared is per value blended field sand costs, a up XX% about on believe activity from third was utilized five basis, We regional regional a to through decrease quarter prices, of while per costs. blend are $X.XX this Mcf a usage. year to our operating cost performing ago, Olmos renewed disposition a the Lease the higher pound
production in the unit to basis sustain a combined LOE our from discipline and cost continued fourth ramp drilling on in our completion expect the recent We to due quarter activity. with
capital high the spend intensity expenditures. We a slickwater to related to approximately $XX the million quarter, Turning completion techniques. third portion invested was large of our in
techniques completed we increase wells We portfolio on have these slickwater barrels XX% wells pounds third of a of averaged lateral, fracture Uno by intensity of Ford of XX%, intensity the and of by quarter. area. in intensity well XX of X,XXX largest using was the proppant immediate the the in first foot across X,XXX foot XX% largest total an and In lateral, been respectively, completion quarter, designs strategically proppant Overall, to-date of which fluid and completed over of Mas employing with stimulation Eagle XX pounds we completed barrels an proppant per frac fluid year. the half the and of proppant our per in of the third our the
through of in pounds we under have We of results Oro pumped. our We these also the we well plan a Grande foot the indicate highest XX hybrid gel-based completion $XX and prior style across per two of these intensity of our designs increase just portfolio our fluid area fracs completed fluid a is historically from from lateral, the average pad higher resulting barrels intensity have XXXX outperformed of guidance. employ million to used. an in Early with proppant medium intensity remainder which completions ever X,XXX they
timing larger days. typically these in days, medium the the out completions the rates budgeting fracs. are XX hybrid optimizing The XX our and associated into while with slickwater frac our we are pushing production reach largest On account to upsize and XX this take flowback scheduling extended side, X periods intensity to fracs operations maximum to to
we evaluating are both actively of addition, the effects proppant of and and intensities. proposition the In analyzing stimulations larger value independently the fluid
cycle exceeding our are drilling time operations Our a expectations standpoint. from
in the also have higher latter drill of the elected and wells faster wells drilling half are interest to working We year.
XX will this activity the investing and a X year. to completed realized result, drill full to thus net be to wells will will we to an more bringing of have an volumes. wells XX net over be year, X for on additional total the drilled from complete late XXXX As The million and impact total XX wells to net in X benefit net to XX, increased wells and to $XX X
fairway. were we to practices we with portions our operate were of able testing these majority million. to the of Ford and high pressure costs delineating $XX offsetting completion incurred of The capital and and While in expenditures. position development Eagle of designs, necessary and high Southern these Gas Partially costs tools non-drilling unanticipated of completion of environment the million the reduce increases, associated new $XX acreage temperature
areas. of an and where net The significant at and Mas. acres isolated first a contiguous where our size X,XXX Grande Mas at we total, swapped midstream Oro net capital acreage locations acres Uno and this reduction this through in Uno acreage an part Grande The lack for XX was X,XXX amount acreage we achieved added stranded Oro In required of with XX scale. would grade have sufficient locations area trade
time cycle achieved hits. program remediate of Through our revised summarize, wells and the capital incorporates to part million preloading impacted wells. designs continued compression, through of To XXXX offset working success the frac need frac of we the wells, $XXX drilling have of $XXX million second our drilling was reduced mitigation completion The testing to high-intensity program. interest higher by range
their and our slickwater to our lateral The larger length We near of stage average flexibility and XH across of above Eagle recent and per Artesia with focus foot. were results, area, spacings design results opportunities. our Fasken these designs by curves. pounds Upper volumes, to XH exceeding a and completed on and today. area, continue stimulation average laterally completed XX pad In maintain adjusted currently their after sand slickwater XXXH the fluid XH, Ford In XH frac the Bravo XXXH The very Recent and liquids based results. and portfolio an treat cut Shifting X,XXX that are further on using type We pleased program basis, to curve X,XXX wells modify commodity Rio feet. optimize XX%. drilling and and days completion are wells intensity XX the test our effectively operational rock. these prices from tighter barrels they all other the on Evans average we considerable with XX% wellbore XH completed to two strategic effective we on type are and designs with exceeds
and well online a area expect fourth bring these the results, currently we completing in two those Artesia pad Given wells quarter. to in are
our in of Artesia continue and our the to rest We area opportunities liquid-rich evaluate portfolio.
gas our Southern area. to Eagle Moving Ford emerging
seeing mentioned, our from are As we Sean areas. strong Uno Mas and performance AWP
These XH. at equivalent of - Our lengths area, foot. and of above of In X,XXX per per gas me, XX we in completed wells the and completed are currently the the and drilled barrels feet we per with of frac completed excuse producing slickwater areas were during have Oro respective months wells these averaged Grande and curves. first XH designs of two all lateral million type ask had XX.X of fluid after day proppant NMC X,XXX flowback production and pounds or their cubic feet
in employed higher efficiency drive and the consultants fares. as with vendors well costs drilling tools and wells. temperature team whole MWD relentless previous eliminate to working NMC from improving The our insights Our tool motor and down been as gained department has analyzing mud cleaning through a
result of XX% average NMC the and improvements, cheaper XH was XX% drill wells. a X XH As than these our faster NMC through of to our
On these day. online million and running two averaging marked of feet we wells rigs. the well each drilling Please equivalent the just of our side, XX.X recap, quarter recently per the refer our full recent productivity cubic a to corporate for presentation quarter of summary second third brought have results. To gas they're
capital production are being Our sales. growth now our being expanded is activity and as to brought wells completed from realized
that, about Gleeson. it prospects we With quarter, are I'll As lie that we turn the fourth shift to ahead. excited over to the