morning. Good
mixed bag The quarter for a Unit was Petroleum. second
wells. On check. drilling and keep the natural weakness dropped Unit downside gas to primarily had we prices realized six rigs continued the in first in running reduced flow spending response, and quarter, in rigs capital Entering on cash NGO oil net focused
Petroleum the of running. By rigs Unit July, had end no
our drilling million production, our our for XXXX of of the first production shutting coupled with during second the increase capital With of over brought of spending wells to XXXX due to of XXXX at the second $XXX the will we our Wilcox quarters. first online Boe XX-day million. million XX Production half estimate and the the third half of now quarter activity, XX.X number and shutdown during
that X% of new our XX% the to will brought compared wells due results horizontal by quarter, Red commodity we X% quarter costs very first first compared production some discuss. Operating increased a on year-over-year production On in XXXX will result our prior half during second our the the and increase mix XX% online higher our Fork the I as increase approximately play concentration quarter. is and by to of quarterly be first were higher increased in to The of over the of wells oil XXXX was of higher the XX% oil quarter-over-quarter. end half drilling to year. oil the of expect approximately and XXXX the production oil strong the The upside, well focus
and expect year. improve we Morgan's Express and over gas forward, next Western due Cheniere's expected Texas in several Looking Panhandle both Pipeline, the Midship to Coast later differentials placed pipeline Oklahoma to the be this in service Gulf Kinder to the months
will per Coast of to it X.X production up will Bcf by out rather than Bcf to of while X Permian move line takeaway capacity the Morgan's the gas Oklahoma Kinder Cheniere's now. is day, Texas line as Gulf coming straight increase per day Panhandle
to even compared to is second approximately our differentials our gas experienced benefit $X.XX realized tighter which to further in to quarter, NYMEX us we Any basis without what realized NYMEX for would gas improvements are price. the XXXX currently for price. gas Mid-Continent
Red During advantage Marchand oil more take our associated play Thomas economics we of with prone the Western quarter, of the better and prospect drilling located Penn both the to second our our accelerated nature within sands play, in Fork Oklahoma operations SOHOT area.
expectations, CapEx top been and results curve on this months line completion play. XX from our SOHOT have over in drilling in with spend program Overall, rates excellent Marchand resulting drilling our of return the last in our
XXXX So, Fork Thomas which well. gross the what exceptionally Boe, oil, in which we're production the continues Boe is well XXX,XXX well Fork in Unit's the basis, IPXX focus a is an liquids field want per which has of came which the play gas perform of is online Red today had Marchand cumulative gas. XX% leader is of and I industry our XX% over initial in. to September day on On natural XXXX, XX% Red to of locked
July, new Fork early three completed. wells were into and Red quarter second horizontal the During
On per the an Even so of IPXX had failure being X,XXX successfully lateral or the the casing an resulted over Boe of the likely in after foot only the casing Wingard the wouldn't lateral disappointing, well been fracking would of have completed. Boe was while XXX IPXX had we failure lateral XXXX have if #XHX, foot XX% X,XXX XX% of lost. day, day, the XXXX per
July The lateral a in with XX% a was XX% which in working XXXX well still that and after per X,XXX interest July, of was well well #XHX, oil. #XHX, early being X,XXX feet. the next end pointing July, of The lateral well has length Saratoga the X,XXX which with last was XXXX that completed production X,XXX completed with XX% end At of day, and the Wingard the of frac the length mid-July of was with day, oil. feet. working per in XX% was and of At the Boe has the being increasing Boe which up Farms producing a producing Unit interest
additional drilled that Fork third Red be two should quarter. has Unit wells completed already in the
at $X,XXX We price of have of the the prospect area per XX,XXX adding net acres been average year. Penn within an since about sands approximately in acre successful beginning the
horizontal drilling XX operated non-operated and XX Our to locations. to at XX now potential Red Fork stands XX inventory
of Red Fork play, wells. expectations have While limited horizontal we continue set high to seven the we have data for a
we what throughout anticipate year will further the additional play. to data from of However, us allowing provide be gathering this clarity to
significant and our from steady have results our a oil made on The our Red Fork in volumes. execution SOHOT program play impact
at will and flow decrease development and strategy aren't that continue we running acreage we cost at low prospects inventory During provide will of intensify and still funding this to with cash drilling we that time our rigs, margins. costs our effort expenses competitive adding
upside organic also that and opportunities continue inventory. will our to We and provide could drilling evaluate cash acquisition margin improve
update. call now John for I'll drilling time, this At the turn company over the to
