Greetings, and welcome to the Halcon Resources Corporation First Quarter 2019 Earnings Conference Call. At this time, all participants are in a listen only mode. As a reminder, this conference is being recorded. It is now my pleasure to introduce your host, Jim Christmas, Chairman of the Board. Thank you, sir.
You may begin.
Thank you. Good morning and thanks for dialing in today. I'll just remind everybody that this conference call contains forward looking statements. For a detailed description of our disclaimer, see our earnings release issued yesterday and posted on our website. We've also updated our investor presentation, which you can access on our website.
I just wanted to begin today briefly to give an update on where we are as it relates to our review of strategic and financial alternatives. As previously indicated, we've hired advisors to assist the Board in developing the optimum go forward strategy for Halcon. Tudor Pickering and Holt and Perella Weinberg Partners were hired in late March to assist in these efforts. I'd say we're about in the middle of the process right now and looking at a range of options including M and A, asset sales and standalone financing alternatives. We don't have anything specific to say today.
We will provide further updates on this as appropriate in the future. We've also engaged a search firm in the process of looking for a new CEO. Finally, although we're obviously not pleased with share price and overall performance, we are encouraged with the progress our team has made in the field, specifically as it relates to handling H2S and getting back to drilling in Monument Draw, which is clearly our best area. We look forward to continuing to develop this acreage position throughout the remainder of 2019. Let me turn the call over Quentin to provide some comments on the Q1 results and recent developments related to our senior credit facility.
Quentin?
Thanks, Jim. Production for the Q1 averaged just above 17,000 barrels of oil equivalent per day, comprised of about 60% oil. We continue to be impacted by sour gas, handling and takeaway constraints in Monument Draw during the quarter. These constraints included multiple days and we were curtailed on our ability to flow sour gas to 3rd party sales line in addition to more than a week of complete downtime at one of our primary 3rd party sour gas sales outlets. As we are unable to flare our sour gas, these curtailments and outages resulted in shut in oil and gas production for many days during the Q1.
We expect fewer issues in relation to 3rd party sour gas outlets going forward now that our Halcon owned H2S treating plant is operational. In fact, after putting our treating plant into operation, we're able to put 4 new wells online in mine withdrawal here in the last month, resulting in current net production in excess of 20,000 BOE a day. John will provide more color on our new treating plant and other operational developments in a moment. Our first quarter oil differential of 90% of NYMEX has improved from the 83% differential seen in the 4th quarter, given improved Midland pricing during the quarter. Our Q1 natural gas differential came in at 25% of NYMEX, which was driven by weak Waha pricing in the quarter.
Our NGL differential for the Q1 was 31%. Our adjusted operating expense, including LOE workover and GTO were elevated in the Q1 for multiple reasons. 1st, on the LOE side, our water disposal costs across the field were higher than previous periods because this is the 1st full quarter where we paid the $0.80 per barrel contracted disposal rate for produced water to Water Bridge under the terms of that agreement. Recurring GTO was higher versus prior quarters, primarily because of extra contract personnel working in Monument Draw to assisting running our operations with the new infrastructure being put in place. G and A expense as adjusted totaled $9,200,000 in the first quarter versus $8,000,000 in the 4th quarter.
The increase in G and A versus 4th quarter was primarily driven by a $1,600,000 credit we booked in the 4th quarter related to a positive legal settlement in that quarter. After adjusting for this settlement, the Q1 adjusted G and A rate was actually a little less than it was in the Q4 of 2018. Similar to the Q4, we had significant a significant amount of non recurring expense in the Q1, primarily related to well level chemical treating of H2S and mine withdrawal. With the operation of our new treating plant, we expect these non recurring costs to go away in the Q2. With respect to P and C CapEx, we incurred approximately $72,000,000 during the Q1.
We spent another $29,000,000 in material costs on infrastructure, seismic and other, with the majority of this spend related to the continued build out of our sour gas handling and treating facilities in Monument Draw. We expect both D and C CapEx and infrastructure CapEx to decline materially over the remainder of 2019. We recently completed an amendment to the borrowing base redetermination with our senior revolving credit lenders, which resulted in our borrowing base being reduced to 225,000,000 dollars Although our reserve profile would justify a higher borrowing base, our senior lenders are not comfortable with our current elevated leverage situation and therefore decided to reduce their commitment to us. We do believe this $225,000,000 borrowing base will provide us with sufficient liquidity until we complete the process we are undergoing with our advisors. We are also considering deferring completions and or dropping a rig in the near term to maximize liquidity as we go through this process.
We can do this without any significant breakage costs as both of our rig contracts are well to well right now. We're not yet revising our capital or production guidance for the year as we've not made a final decision to drop rigs. I would note that if we do pursue a new financing structure that provides more liquidity and flexibility than our revolver does, we should be allowed to continue with the 2 rig program for the rest of the year. With that, I will turn the call over to John for comments.
Thanks, Quentin. As Quentin indicated, we are pleased to have our Halconon liquid redox H2S treatment plant online in Monument Draw. We commissioned the 1st train of this facility the 1st week of April and the 2nd train went operational in the 3rd week of April. The plant is currently treating approximately 11,000,000 cubic feet a day of gas with average H2S concentrations of approximately 30,000 to 40,000 PPM. The treating cost for gas at these levels is roughly $2.50 per Mcf.
The capacity of the plant at these concentrations of H2S is in the range of 14000000 to 15000000 cubic feet per day. The treating capacity of this plant, in addition to the arrangements we have with 3rd party sour gas sales outlets, provides us with ample treating capacity for more than a year with 2 rigs running in Monument Draw. On a related note, we continue to pursue an acid gas injection well in Monument Draw, which would materially reduce the treating cost of gas, while at the same time significantly increase our treating capacity. We hope to have our permit approved for this AGI well in the Q3 of 2019 with the AGI well becoming operational in mid-twenty 20 if approved. We have brought 4 new Wolfcamp wells online in Monnit Draw over the last month or so given our increased treating capacity here.
2 of these wells were 5,000 foot laterals, which had an average 30 day PIP rate of 1,002 BOE per day at 83% oil. The other 2 wells were bought online more recently and have not yet reached peak IP rates. These wells are currently averaging over 1,000 barrels per day equivalent at 82% oil. All 4 of these wells' early time production rates are in excess of our type curves. In addition, we have returned the Sealy Ranch 7,506 well to production this past weekend.
This well was shut in early October of 2018 given elevated levels of H2S in the gas stream. This well was cleaning up and looked to be a very good producer before it was shut in. With our additional H2S handling capacity now operational, we have all 18 horizontal wells online in Monument Draw. In West Quito Draw, we had 5 more 10,000 foot lateral looking at wells come online since the beginning of this year. In addition to the first two wells we reported as a part of our year end earnings release.
Overall, oil cuts on these wells have averaged around 35%, which is below our expectations. Given the weak gas pricing we are seeing in the basin, we have elected to pause drilling in the southern area of West Quito Draw in the near term. We currently have both of our rigs working in Monument Draw and plan to return a rig to the northern area of West Quito Draw in early 2020, where we expect the wells to have a much higher oil cut than what we have seen in the southern area. That is all I have for today. I'll turn the call back over to Quinton for closing remarks.
Thanks everyone for your interest and feel free to reach out to us with any questions you may have. Thank you.
Ladies and gentlemen, this does conclude today's teleconference. Please disconnect your lines at this time. Thank you for your participation and have a wonderful